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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549


Form 6-K

REPORT OF FOREIGN ISSUER
Pursuant to Rule 13a-16 or 15d-16 of
the Securities Exchange Act of 1934

For the month of May 2007

Eni S.p.A.
(Exact name of Registrant as specified in its charter)

Piazzale Enrico Mattei 1 - 00144 Rome, Italy
(Address of principal executive offices)


     (Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.)

Form 20-F x                    Form 40-F o


     (Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2b under the Securities Exchange Act of 1934.)

Yes o                    No x

     (If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b):               )



 


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TABLE OF CONTENTS

 

Press Release dated May 4, 2007

Press Release dated May 11, 2007

Press Release dated May 24, 2007

Press Release dated May 28, 2007

Press Release dated May 28, 2007

Press Release dated May 30, 2007

Press Release dated May 30, 2007

Press Release dated May 31, 2007

Fact book 2006

Report "Eni in 2006"

Report on the First Quarter 2007

Analist presentation - 1Q 07 results

Annual Report at December 31, 2006 (including the Report of External Auditors)

 


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SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, hereunto duly authorised.

         
  Eni S.p.A.
 
 
         
    Name: Fabrizio Cosco   
    Title:   Company Secretary   
 

Date: May 31, 2007

 


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Eni convenes Board of Directors

 

 

San Donato Milanese, 4 May 2007 - Eni’s Board of Directors will be held on 10 May 2007 in San Donato Milanese (Milan) to examine Eni’s Quarterly Report at 31 March 2007.

 

Company Contacts:

Press Office: +39 0659822040 / +39 0252031287

Switchboard number: +39-0659821
Free Number: 800940924

ufficio.stampa@eni.it

segreteriasocietaria.azionisti@eni.it

investor.relations@eni.it

Internet page: www.eni.it

 


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ENI ANNOUNCES RESULTS FOR THE FIRST QUARTER OF 2007

2007-2010 PRODUCTION GROWTH TARGET RAISED FROM 3% TO 4%

San Donato Milanese, May 11, 2007 - Eni, the international oil and gas company today announces its group results for the first quarter of 2007 (unaudited).

Paolo Scaroni, Chief Executive Officer, commented:
“The first quarter 2007 was affected by weaker oil prices, a strong euro, and low seasonal gas and product sales due to unusually mild weather conditions. Despite these, Eni managed to deliver excellent results among the best in the European oil & gas sector. In the first months of 2007 we undertook a successful acquisition campaign purchasing attractive oil assets which will make an important contribution to our growth strategy in the following years.”

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
    Summary Group results (million euro)              
3,957   Operating profit   5,595   5,105   (8.8 )
4,776   Adjusted operating profit (a)   5,533   5,253   (5.1 )
1,520   Net profit (b)   2,974   2,588   (13.0 )
0.41   - per ordinary share (euro) (c)   0.80   0.70   (12.5 )
1.06   - per ADR ($) (c) (d)   1.92   1.83   (4.7 )
2,355   Adjusted net profit (a) (b)   2,954   2,680   (9.3 )
0.64   - per ordinary share (euro) (c)   0.79   0.73   (7.6 )
1.65   - per ADR ($) (c) (d)   1.90   1.91   0.5  

     
 
 
     
(a)   For a detailed explanation of adjusted operating profit and net profit see page 16.
(b)   Profit attributable to Eni shareholders.
(c)   Fully diluted. Dollar amounts are converted on the basis of the average EUR/USD exchange rate quoted by the ECB for the periods presented.
(d)   One ADR (American Depositary Receipt) is equal to two Eni ordinary shares.

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Financial highlights

Operational highlights and trading environment

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
    Key operating data                  
1,796   Production of hydrocarbons   (kboe/d)   1,827   1,734   (5.1 )
1,079   Liquids   (kbbl/d)   1,143   1,030   (9.9 )
4,132   Natural gas   (mmcf/d)   3,920   4,061   3.6  
26.93   Worldwide gas sales   (bcm)   31.20   28.14   (9.8 )
1.06   of which: upstream sales       1.12   1.07   (4.5 )
7.79   Electricity sold   (TWh)   7.73   7.61   (1.6 )
3.13   Retail sales of refined products in Europe   (mmtonnes)   2.93   2.88   (1.7 )

     
 
 

(1)   Non-GAAP financial measures disclosed throughout this press release are accompanied by explanatory notes and tables to help investors to gain a full understanding of said measures in line with guidance provided for by CESR recommendation No. 2005-178b. See pages 22 and 23 for leverage, net borrowings and ROACE, respectively.

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Portfolio developments

Outlook for 2007

The outlook for Eni in 2007 remains positive, with key business trends for the year as follows:
- Production of liquids and natural gas is forecast to remain at the same level as 2006 (in 2006 oil and gas production averaged 1.77 mmboe/d). Additional production expected in the second half of the year from acquired properties in the Gulf of Mexico and Congo and the expected build-up in gas production in Libya will enable Eni to recover the first quarter decline in production due to escalating social unrest in Nigeria and the loss of the Dación oilfield in Venezuela;
- Sales volumes of natural gas worldwide are expected to increase by 1% over 2006 (actual sales volumes in 2006 were 97.48 bcm). Major increases are expected in certain target markets in the Rest of Europe, mainly in the Iberian Peninsula, the North of Europe, France and Germany/Austria markets;
- Sales volumes of electricity are expected to slightly increase from 2006 (actual volumes in 2006 were 31.03 TWh);
- Refining throughputs on Eni’s account are forecast to slightly decrease from 2006 (actual throughputs in 2006 were 38.04 mmtonnes) due to expiration of a processing contract at the Priolo refinery owned by a third party late in 2006, to be offset by higher throughputs expected at the Gela, Livorno and Taranto refineries;
- Retail sales of refined products are expected to slightly increase from 2006 (actual volumes sold in 2006 were 12.48 mmtonnes). Increases are expected on both the Italian and European markets due to the entry into service of new outlets, and also following the acquisition of stations in target markets.

In 2007 management expects Eni’s capital expenditure on exploration and capital projects to amount to approximately euro 10.5 billion, representing a 34% increase over 2006. Approximately 86% of this capital expenditure programme is expected to be deployed in the Exploration & Production, Gas & Power and Refining & Marketing divisions. Furthermore, acquisitions of assets and interests amounting to euro 9.2 billion are forecast for 2007, mainly related to: (i) the agreed purchase of ex-Yukos assets; (ii) the other agreements which are expected to be finalised by the end of the year, including the purchase of upstream assets in the Gulf of Mexico and Congo, and a retail station network in the Central-Eastern Europe. Assuming Gazprom exercises its call options to purchase a 20% interest in OAO Gazprom Neft and a 51% interest in ex-Yukos gas assets from Eni, net cash outflows used in investing activities will decrease to euro 16.2 billion.
On the basis of the expected cash outflows for this capital expenditure and acquisition programme, and shareholders remuneration, also assuming a 55$/barrel scenario for the Brent crude oil, Eni foresees its leverage to range from 0.3 to 0.4 by the end of the year, depending on the exercise of the above mentioned call options by Gazprom.

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Disclaimer
Due to the seasonality in demand for natural gas and certain refined products and the changes in a number of external factors affecting Eni’s operations, such as prices and margins of hydrocarbons and refined products, Eni’s results from operations and changes in net borrowings for the first quarter cannot be extrapolated on an annual basis.

Cautionary statement
This press release, in particular the statements under the section “Outlook”, contains certain forward-looking statements particularly those regarding capital expenditure, development and management of oil and gas resources, dividends, share repurchases, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets, and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future.
Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors and other factors discussed elsewhere in this document.

 

*      *      *

Contacts
E-mail:
segreteriasocietaria.azionisti@eni.it

Investor Relations
E-mail:
investor.relations@eni.it
Tel.: +39 0252051651 - fax: +39 0252031929

Eni Press Office
Casella e-mail:
ufficiostampa@eni.it
Tel.: +39 0252031287 - +39 0659822040

*      *      *

Eni
Società per Azioni Roma, Piazzale Enrico Mattei, 1
Capitale sociale: euro 4.005.358.876 i. v.
Registro Imprese di Roma, c. f. 00484960588
Tel. +39-0659821 - Fax +39-0659822141

 

*      *      *

 

This press release and Eni’s Report on Group Results for the first quarter 2007 (unaudited) are also available on the Eni web site: “www.eni.it”.

About Eni
Eni is one of the leading integrated energy companies in the world operating in the oil and gas, power generation, petrochemicals, engineering and construction industries. Eni is present in 70 countries and is Italy’s largest company by market capitalisation.

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Summary results for the first quarter

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
21,416     Net sales from operations   23,584     21,913     (7.1 )
3,957     Operating profit   5,595     5,105     (8.8 )
341     Exclusion of inventory holding (gains) losses   (94 )   155        
478     Exclusion of special items:   32     (7 )      
      of which:                  
184     - non recurring items                  
294     - other special items   32     (7 )      
4,776     Adjusted operating profit   5,533     5,253     (5.1 )
1,520     Net profit pertaining to Eni   2,974     2,588     (13.0 )
213     Exclusion of inventory holding (gains) losses   (59 )   97        
622     Exclusion of special items:   39     (5 )      
      of which:                  
184     - non recurring items                  
438     - other special items   39     (5 )      


     

 

 

2,355     Adjusted net profit pertaining to Eni   2,954     2,680     (9.3 )


     

 

 

178     Net profit of minorities   156     155     (0.6 )
2,533     Adjusted net profit   3,110     2,835     (8.8 )
      Break down by division (a)                  
1,304          Exploration & Production   2,095     1,409     (32.7 )
873          Gas & Power   879     1,159     31.9  
115          Refining & Marketing   86     113     31.4  
141          Petrochemicals   16     79     393.8  
131          Engineering & Construction   87     145     66.7  
(85 )        Other activities   (58 )   (50 )   13.8  
57          Corporate and financial companies   6     (86 )   ..  
(3 )        Effect of unrealized profit in inventory (b)   (1 )   66     ..  
                         
      Net profit                  
0.41     per ordinary share (euro)   0.80     0.70     (12.5 )
1.06     per ADR ($)   1.92     1.83     (4.7 )
                         
      Adjusted net profit                  
0.64     per ordinary share (euro)   0.79     0.73     (7.6 )
1.65     per ADR ($)   1.90     1.91     0.5  
                         
3,684.7     Weighted average number of outstanding shares (c)   3,726.0     3,679.0     (1.3 )
1,778     Net cash provided by operating activities   5,863     5,563     (5.1 )
2,944     Capital expenditure   1,340     2,013     50.2  


     

 

 

     
(a)   For a detailed explanation of adjusted net profit by division see page 16.
(b)   Unrealized profit in inventory concerned intra-group sales of goods and services recorded at period end in the equity of the purchasing business segment.
(c)   Assuming dilution.

Trading environment indicators

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
59.68   Average price of Brent dated crude oil (a)   61.75   57.75   (6.5 )
1.290   Average EUR/USD exchange rate (b)   1.202   1.310   9.0  
46.26   Average price in euro of Brent dated crude oil   51.37   44.08   (14.2 )
2.18   Average European refining margin (c)   2.95   3.06   3.7  
1.69   Margin Average European refining margin in euro   2.45   2.34   (4.5 )
3.6   Euribor - three month rate (%)   2.6   3.8   46.2  
5.3   Libor - three month dollar rate (%)   4.7   5.3   12.8  

     
 
 
     
(a)   In USD dollars per barrel. Source: Platt’s Oilgram.
(b)   Source: ECB.
(c)   In USD per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations based on Platt’s Oilgram data.

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Bottom line
Eni’s net profit for the first quarter of 2007 was euro 2,588 million, down euro 386 million from the first quarter of 2006, or 13%, due primarily to a lower operating performance (down euro 490 million, or 8.8%) as a result of a decline in the Exploration & Production division, partially offset by a positive performance delivered by Eni's downstream and the Engineering & Construction businesses. This reduction in net profit was also due to higher net financial expenses mainly owing to losses on the fair value evaluation of certain financial derivative instruments.

Eni’s adjusted net profit amounted to euro 2,680 million, down 9.3% from the first quarter 2006. Adjusted net profit is arrived at by excluding an inventory holding loss of euro 97 million and special income of euro 5 million net.

Divisional performance
The decline in the Group adjusted net profit was owed to the reduction of adjusted net profit registered in the Exploration & Production division (down euro 686 million or 32.7%), due to a weaker operating performance (down euro 1,119 million or 26.3%) which was adversely impacted by the appreciation of the euro over the dollar (9.0%), a decline in production sold (down 9.5 mmboe/d), lower oil realizations in dollars (oil down 3.3%), and higher exploration expenses.

The decline in the adjusted net profit of the Exploration & Production division was partly offset by a higher adjusted net profit reported in the divisions:

Net borrowings and cash flow
Net borrowings as of March 31, 2007 amounted to euro 3,852 million, decreasing by euro 2,915 million from December 31, 2006. Net cash provided by operating activities totalled euro 5,563 million. Main cash outflows related to: (i) capital expenditure totalling euro 2,013 million; (ii) the repurchase of own shares for euro 203 million by Eni SpA and euro 242 million by Snam Rete Gas SpA.

Leverage, the ratio of net borrowings to shareholders’ equity including minority interest decreased to 0.09, from 0.16 at December 31, 2006.

Repurchase of own shares
From January 1 to March 31, 2007 a total of 8.52 million own shares were purchased by the company for a total amount of euro 203 million (representing an average cost of euro 23.847 per share). Since the inception of the share buy-back programme (September 1, 2000), Eni has repurchased 344 million shares, equal to 8.58% of outstanding capital stock, at a total cost of euro 5,716 million (representing an average cost of euro 16.638 per share).

Capital expenditure
Capital expenditure in the first quarter of 2007 amounted to euro 2,013 million (euro 1,340 million in the first quarter 2006) and related mainly to:

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Post closing events

Upstream asset acquisition in the Gulf of Mexico
On April 30, 2007 Eni agreed to acquire the Gulf of Mexico upstream activity of Dominion, one of the major American energy companies listed on the New York stock exchange at the agreed price equal to US $4,757 million, inclusive of exploration assets for US $680 million.
The transaction, includes production, development and exploration assets located in deepwater Gulf of Mexico. The acquisition will increase Eni’s equity production in the Gulf of Mexico from the current 36,000 boepd to more than 110,000 boepd in the second half of 2007 and the proved and probable equity reserves by 222 million boe, at an implied cost per barrel of US $18.4. From 2007-2010 production from the acquired assets is expected to average more than 75,000 boepd.
In addition, Eni will further enhance its portfolio in the Gulf of Mexico thanks to new leases with significant exploration potential; approximately 60% of these leases are operated.
The transaction is subject to government approvals, 30-days notice to holders of certain preferential rights to purchase (which apply to less than 5% of total reserves), and to other customary precedent conditions. Final agreement is anticipated to take place on July 2, 2007.


Yukos asset acquisition
On April 4, 2007 Eni, through its partnership in EniNeftegaz (60% Eni, 40% Enel SpA) acquired Lot 2 in the Yukos liquidation procedure for a total price of $5.83 billion. Lot 2 includes:
• 100% of OAO Arctic Gas Co
• 100% of ZAO Urengoil Inc
• 100% of OAO Neftegaztechnologia.
These three companies own 5 oil and gas fields and condensate fields and parts of 3 others in the Yamal Nenets (YNAO) region, the world’s largest gas producing region. Together they have large oil and gas reserves.
Eni and Enel have offered Gazprom an option to acquire 51% participation interest in these assets within two years. In the event that Gazprom exercises its call option, the assets will be operated through a joint venture between Eni and Gazprom which will have access to Eni’s most advanced technologies.
Lot 2 also includes:
• various minor assets that will be sold or liquidated and
• 20% of OAO Gazprom Neft which will be wholly owned by Eni.

Eni offered Gazprom an option to acquire 20% participation interest in OAO Gazprom Neft within two years, at a total price of $3.7 billion, in addition to financial expenses relating to the acquisition. These agreements are an additional step in implementing the Strategic Partnership between Eni and Gazprom signed in November 2006, under which the two companies established an alliance to develop upstream, midstream and downstream energy projects inside and outside of Russia.

Acquisition of the retail station network in Czechia, Slovakia and Hungary
On April 27, 2007 Eni and ExxonMobil Central Europe Holding GmbH signed an agreement for the sale of shares of Esso spol sro (Esso Czechia), Esso Slovensko spol sro (Esso Slovakia) and ExxonMobil Hungary Kft to Eni. The agreement, subject to the approval by relevant authorities, includes ExxonMobil's retail station network in the three countries, totalling 102 stations and its aviation business at the Prague and Bratislava airports.
Additionally, the lubricants business conducted in these countries by ExxonMobil Petroleum and Chemical, BVBA, Brussels, is included in the transaction.

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Acquisition of 70%, including operatorship, of the Nikaitchuq Field in Alaska
On April 11, 2007 Eni acquired 70% and the operatorship of the Nikaitchuq Field, located on and offshore in the North Slope of Alaska. Eni, which already owned a 30% stake in the field, now retains the 100% working interest. Eni acquired the additional interest and operatorship as the result of an agreement with Kerr-McGee Oil and Gas Corporation, a wholly owned subsidiary of Anadarko Petroleum Corporation.
Nikaitchuq would be the first development project operated by Eni in Alaska. Successful appraisal drilling has been completed, confirming the potential viability of the development project. Plans for a phased development are currently being evaluated with the target of sanctioning the project by year end, and first oil to flow by the end of 2009. The Nikaitchuq project comprises the drilling of approximately 80 wells, out of which 32 are located onshore and the remaining from an offshore artificial island. All wells will then be tied back to a production facility located at Oliktok Point to reach a production of 40,000 b/d. Total investment will amount to approximately $900 million.

Memorandum of Understanding for the acquisition of an interest in Angola LNG Ltd
On April 2, 2007 Eni and Sonangol signed a Memorandum of Understanding for the acquisition of a 13.6% stake in Angola LNG Limited Consortium (A-LNG). This company is responsible for the construction of an LNG plant in Soyo, 300 km north Luanda, with a yearly capacity of 5 million tonnes.
Upon completion of this agreement, Angola LNG Limited’s shareholding structure will be as follows: Sonangol 22.8%, Chevron 36.4%, Eni 13.6%, Total 13.6% and BP 13.6%.
The project, for a total investment of approximately $4 billion, has been approved by the Angolan Government and Parliament. It envisages, for 28 years, the development of 220 billion cubic meters of gas, the production of 128 million tons of LNG, 104 million barrels of condensate and 257 million barrels of LPG.
LNG will be directed to the United States market and will be delivered to the re-gasification plant of Pascagoula, in the Gulf of Mexico, in which Eni, following this agreement, will acquire re-gasification capacity of 5 billion cubic meters per year.




Other information

The Board also approved the merger into the parent company of Eni’s wholly-owned subsidiaries AgipFuel, Napoletana Gas Clienti and Siciliana Gas. The relevant merger proposals were approved by the Board on March 29, 2007.




Financial and operating information by division for the first quarter 2007 is provided in the following pages.

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Exploration & Production

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
      Results (million euro)                      
6,152     Net sales from operations       7,412     6,361     (14.2 )
3,141     Operating profit       4,308     3,132     (27.3 )
54     Exclusion of special items:       (57 )            
51     - asset impairments                      
(7 )   - gains on disposal of assets       (57 )            
10     - provision for redundancy incentives                      
3,195     Adjusted operating profit       4,251     3,132     (26.3 )
(22 )   Net financial incomes (expenses) (a)       (17 )   (35 )      
(18 )   Net income (expenses) from investments (a)       10     10        
(1,851 )   Income taxes (a)       (2,149 )   (1,698 )      
58.7     Tax rate   (%)   50.6     54.7        
1,304     Adjusted net profit       2,095     1,409     (32.7 )
      Results also include:                      
1,418     - amortisations and depreciations       1,095     1,240     13.2  
419     - of which amortisations of exploration expenditure       187     375     ..  
1,937     Capital expenditure       961     1,366     42.1  


         

 

 

      Production (b) (c)                      
1,079     Liquids (d)   (kbbl/d)   1,143     1,030     (9.9 )
4,132     Natural gas   (mmcf/d)   3,920     4,061     3.6  
1,796     Total hydrocarbons   (kboe/d)   1,827     1,734     (5.1 )


         

 

 

      Average realisations                      
54.85     Liquids (d)   ($/bbl)   56.27     54.39     (3.3 )
5.39     Natural gas   ($/mmcf)   5.23     2.30     1.3  
45.53     Total hydrocarbons   ($/boe)   46.71     45.12     (3.40 )


         

 

 

      Average oil market prices                      
59.68     Brent dated   ($/bbl)   61.75     57.75     (6.5 )
46.26     Brent dated   (euro/bbl)   51.37     44.08     (14.2 )
59.94     West Texas Intermediate   ($/bbl)   63.29     57.99     (8.4 )
235.20     Gas Henry Hub   ($/kcm)   271.90     266.60     (1.9 )


         

 

 

     
(a)   Excluding special items.
(b)   Supplementary operating data is provided on page 26.
(c)   Includes Eni's share of production of equity-accounted entities.
(d)   Includes condensates.

Adjusted operating profit for the first quarter 2007 was euro 3,132 million, a decrease of euro 1,119 million from the first quarter 2006, or 26.3%), due primarily to:

The adjusted net profit was euro 1,409 million, down euro 686 million from the first quarter of 2006. This result was impacted by a weaker operating performance and a higher tax rate (increased from 50.6% to 54.7%), primarily due to the Algerian windfall tax on upstream earnings effective August 1, 2006 and the supplemental tax rate applicable to profit earned in North Sea operations as enacted by the British Government in July 2006.

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Oil and natural gas production in the first quarter of 2007 averaged 1,734 kboe/d, a decrease of 93 kboe/d from the same period of the previous year (down 5.1%). This reduction was due primarily to the unilateral cancellation of the Dación field service contract by the Venezuelan state company PDVSA with effect from April 1, 2006 (down 60 kboe/d) and social unrest in Nigeria. Factoring in these effects, oil and natural gas production level was in line with the first quarter 2006. Production increases were achieved mainly in Libya, Kazakhstan and the Gulf of Mexico offsetting mature field declines in Italy and facility shutdowns.

Daily production of oil and condensates (1,030 kbbl) decreased by 113 kbbl, or 9.9% from the first quarter of 2006. Production decreases were reported mainly in Venezuela and Nigeria due to the above mentioned causes and in the United Kingdom due to a technical problem in the Elgin/Franklin field (Eni's interest 21.87%) and ordinary maintenance shutdowns at other facilities. In Italy a few technical problems occurred at the FPSO operating the Aquila field. Significant increases were registered in Kazakhstan, and the United States.

Daily production of natural gas for the first quarter (4,061 mmcf/d) increased by 141 mmcf/d, or 3.6%, mainly as a result of the build-up of the Bahr Essalam field offshore Libya, full operations at train fifth at Bonny LNG plant in Nigera, a better performance of Norway’s largest fields, and full production of Bayu Undan gas field offshore Australia. Gas production in Italy decreased due to mature field declines.

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Gas & Power

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
      Results (million euro)                      
8,170     Net sales from operations       9,134     8,543     (6.5 )
1,303     Operating profit       1,199     1,641     36.9  
(41 )   Exclusion of inventory holding (gains) losses       (30 )   40        
7     Exclusion of special items:       34     2        
      of which:                      
      Non-recurring items                      
7     Other special items       34     2        
2     - environmental provisions       20              
15     - provisions for redundancy incentives       14     2        
(10 )   - other                      
1,269     Adjusted operating profit       1,203     1,683     39.9  
832     Market and Distribution       705     1,177     67.0  
286     Transport in Italy       305     286     (6.2 )
144     Transport outside Italy       154     163     5.8  
7     Power generation (a)       39     57     46.2  
(1 )   Net financial incomes (expenses) (b)       6     3        
97     Net income (expenses) from investments (b)       137     115        
(492 )   Income taxes (b)       (467 )   (642 )      
36.0     Tax rate   (%)   34.7     35.6        
873     Adjusted net profit       879     1,159     31.9  
453     Capital expenditure       151     221     46.4  


         

 

 

      Natural gas sales   (bcm)                  
14.09     Italy to third parties (*)       17.47     15.41     (11.8 )
1.55     Own consumption (*)       1.47     1.39     (5.4 )
8.14     Rest of Europe (*)       8.57     7.90     (7.8 )
0.12     Outside Europe       0.16     0.10     (37.5 )
23.90     Sales to third parties and own consumption of consolidated companies       27.67     24.80     (10.4 )
1.97     Sales of Eni's affiliates (net to Eni)       2.41     2.27     (5.8 )
0.01     Italy (*)       0.01     0.01        
1.83     Rest of Europe (*)       2.33     2.10     (9.9 )
0.13     Outside Europe       0.07     0.16     ..  
25.87     Total sales and own consumption (G&P)       30.08     27.07     (10.0 )
1.06     Upstream in Europe       1.12     1.07     (4.5 )
26.93     Worldwide sales       31.20     28.14     (9.8 )
26.68     Total sales in Europe       30.97     27.88     (10.0 )
                             
22.45     Gas volumes transported in Italy   (bcm)   24.89     23.51     (5.5 )
14.97     Eni       16.12     15.55     (3.5 )
7.48     On behalf of third parties       8.77     7.96     (9.2 )
                             
7.79     Electricity sold   (TWh)   7.73     7.61     (1.6 )


         

 

 

     
(a)   Starting on January 1, 2007, results from marketing of electricity have been included in results from market and distribution activities following an internal reorganization. As a consequence of this, electricity generation activity conducted by EniPower subsidiary comprises only results from production of electricity. Prior quarter results have not been restated.
(b)   Excluding special items.
(*)   Market segments with asterisk merge into "Total sales in Europe".

The adjusted operating profit of the Gas & Power division totalled euro 1,683 million, up euro 480 million or 39.9% from the first quarter of 2006, reflecting primarily:

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These positives were partly offset by a decline in natural gas sales (down 2.87 bcm, or 10.4%), a result of lower European gas demand because of the unusually mild weather conditions of the first quarter 2007, partly offset by a growth in sales in certain target markets in the rest of Europe. Lower gas demand negatively affected the operating performance of transport activities in Italy and volumes distributed on low pressure networks. Sales volumes of electricity decreased by 0.12 TWh, or 1.6%.

Special charges for the quarter referred to redundancy incentives (euro 2 million).

The adjusted net profit was euro 1,159 million, up euro 280 million, or 31.9%, reflecting the increased adjusted operating profit.

Eni’s worldwide natural gas sales for the first quarter of 2007 amounted to 28.14 bcm, including own consumption and sales by affiliates and upstream sales in Europe, with a decrease of 3.06 bcm from the first quarter of 2006, or 9.8%. This decline was impacted by lower seasonal gas sales due to unusually mild winter time.

In an increasingly competitive market, sales in the Italian market were 15.41 bcm with a decrease of 2.06 bcm, or 11.8%. All market segments posted sale volumes declines from the first quarter of 2006:

Gas sales in the Rest of Europe were 7.9 bcm with a decrease of 0.67 bcm, or 7.8%, due to:

These decreases were partly offset by increases in the supplies to the Turkish (up 0.34 bcm) and Spanish (up 0.18 bcm) markets.


(1)   For more details on Resolution No. 79/2007 see the “Report on the First Quarter of 2007 - Operating Review - Gas & Power” published with this press release.

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Table of Contents

Refining & Marketing

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
      Results (million euro)                      
8,579     Net sales from operations       9,280     7,943     (14.4 )
(386 )   Operating profit       89     (10 )   ..  
386     Exclusion of inventory holding (gains) losses       (47 )   112        
148     Exclusion of special items:       47     18        
      of which:                      
109     Non-recurring items                      
39     Other special items       47     18        
13     - asset impairments                      
27     - environmental provisions       44     17        
30     - provisions for redundancy incentives       5     1        
4     - provision to the reserve for contingencies       1              
(35 )   - other       (3 )            
148     Adjusted operating profit       89     120     34.8  
      Net financial incomes (expenses) (a)                      
31     Net income (expenses) from investments (a)       47     51     8.5  
(64 )   Income taxes (a)       (50 )   (58 )   16.0  
35.8     Tax rate   (%)   36.8     33.9        
115     Adjusted net profit       86     113     31.4  
272     Capital expenditure       95     134     41.1  


         

 

 

      Global indicator refining margin                      
2.18     Brent ($/bbl)       2.95     3.06     3.7  
1.69     Brent (euro/bbl)       2.45     2.34     (4.5 )
4.87     Ural ($/bbl)       5.76     6.07     5.4  


         

 

 

      Refining throughputs and sales   (mmtonnes)                  
9.05     Refining throughputs on own account Italy       7.49     7.86     4.9  
1.20     Refining throughputs on own account Rest of Europe       1.12     1.14     1.8  
7.36     Refining throughputs of wholly-owned refineries       5.86     6.67     13.8  
100     Utilization rate of balanced capacity   (%)   100     100        
                             
2.16     Retail sales Italy       2.06     1.98     (3.9 )
0.97     Retail sales rest of Europe       0.87     0.90     3.4  
3.13     Sub-total retail sales       2.93     2.88     (1.7 )
2.93     Wholesale Italy       2.94     2.61     (11.2 )
1.06     Wholesale Rest of Europe       1.03     1.05     1.9  
0.10     Wholesale Rest of World       0.10     0.13     30.0  
5.96     Other sales       5.32     5.67     6.6  
13.18     Sales       12.32     12.34     0.2  


         

 

 

      Refined product sales by region   (mmtonnes)                  
7.71     Italy       7.55     7.30     (3.3 )
2.03     Rest of Europe       1.90     1.95     2.6  
3.44     Rest of World       2.87     3.09     7.7  


         

 

 

     
(a)   Excluding special items.

The Refining & Marketing division reported an adjusted operating profit of euro 120 million, representing an increase of euro 31 million from the first quarter of 2006, or 34.8%. This increase reflected primarily a better operating performance delivered by the refining activity, which was boosted by higher processed volumes and better yields also in light of lower maintenance shutdowns. The benefit of higher refining margins (margins on the Brent crude oil were up 0.11 dollar/bbl, or 3.7%) was more than offset by thenegative impact of the

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euro appreciation over the dollar. Marketing activities in Italy reported a lower operating profit due mainly to lower retail margins and a decline in wholesale volumes as a consequence of lower heating oil demand in Italy particularly in the thermoelectric sector caused by a relatively mild winter weather.

The adjusted net profit was euro 113 million, up euro 27 million, or 31.4%, due to the improved operating performance.

Special charges excluded from the adjusted operating profit for the first quarter 2007 were euro 18 million, reflecting environmental provisions and provisions for redundancy incentives.

Refining throughputs on Eni’s own account increased by 390 ktonnes from the first quarter of 2006, to 9 mmtonnes, or 4.5%. This increase was due to lower maintenance shutdowns in Livorno and Venice refineries, partly offset by expiration of a processing contract at the Priolo refinery owned by a third party and lower throughputs at the Gela and Taranto refineries due to planned maintenance shutdowns.

The wholly-owned refineries throughputs increased by 0.81 mmtonnes from the first quarter of 2006, to 6.67 mmtonnes, or 13.8%, mainly in the Livorno, Taranto and Venice refineries. The wholly-owned refinery utilisation rate was 100% based on the utilisation rates of refinery balanced capacity.

Sales of refined products increased by 20 ktonnes from the first quarter of 2006, to 12.34 mmtonnes, or 0.2%, due to: (i) higher volumes sold to oil companies and traders in Italy, partly offset by lower volumes sold to the petrochemical sector reflecting expiration of a processing contract at the Priolo refinery (overall up 350 ktonnes); and (ii) higher sales on both the retail and wholesale markets in the Rest of Europe (up 50 ktonnes). These positives were partly offset by a decline in both the retail and wholesale markets in Italy (down 410 ktonnes) due to the impact of milder weather in the first quarter 2007 and competitive pressure.

Sales of refined products on the retail market in Italy decreased by 80 ktonnes from the first quarter of 2006, to 1.98 mmtonnes, or 3.9%, primarily due to competitive pressure and lower demand.
Sales in the retail market in the Rest of Europe increased by 30 ktonnes from the first quarter of 2006, to 0.9 mmtonnes, or 3.4%, mainly in Spain.

Sales in the wholesale market in Italy decreased by 330 ktonnes from the first quarter of 2006, to 2.61 mmtonnes, or 11.2%, due to lower demand for heating products particularly from the thermoelectric sector caused by unusually milder weather.
Sales on the wholesale market in the Rest of Europe increased by 20 ktonnes, to 1.05 mmtonnes, or 1.9%, primarily reflecting the increase in sales in the Czech Republic.

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Summarized group profit and loss account

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
21,416     Net sales from operations   23,584     21,913     (7.1 )
302     Other income and revenues   209     281     34.4  
(15,874 )   Operating expenses   (16,739 )   (15,462 )   7.6  
(184 )   of which non recurring items                  
(1,887 )   Depreciation, amortisation and impairments   (1,459 )   (1,627 )   (11.5 )


     

 

 

3,957     Operating profit   5,595     5,105     (8.8 )
52     Net financial income (expense)   42     (133 )   ..  
157     Net income from investments   240     202     (15.8 )


     

 

 

4,166     Profit before income taxes   5,877     5,174     (12.0 )
(2,468 )   Income taxes   (2,747 )   (2,431 )   11.5  


     

 

 

59.2     Tax rate (%)   46.7     47.0     ..  
1,698     Net profit   3,130     2,743     (12.4 )
      pertaining to:                  
1,520     - Eni   2,974     2,588     (13.0 )
178     - minority interest   156     155     (0.6 )


     

 

 

1,520     Net profit pertaining to Eni   2,974     2,588     (13.0 )
213     Exclusion of inventory holding (gain) loss   (59 )   97        
622     Exclusion of special items:   39     (5 )      
      of which:                  
184     - non-recurring items                  
438     - other special items   39     (5 )      


     

 

 

2,355     Eni's adjusted net profit (1)   2,954     2,680     (9.3 )


     

 

 

     
(1)   Adjusted operating profit and net profit are before inventory holding gains or losses and special items. For an explanation of these measure and reconciliation of adjusted operating profit and net profit to reported operating profit and net profit see below.

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NON-GAAP Measures

Reconciliation of reported operating profit and net profit to results on an adjusted basis

Management evaluates Group and business performance on the basis of adjusted operating profit and adjusted net profit, which are arrived at by excluding inventory holding gains or losses and special items. Further, finance charges on finance debt, interest income, charges or income deriving from the fair value evaluation of derivative financial instruments held for trading purposes, and exchange rate differences are excluded when determining adjusted net profit of each business segment.
The taxation effect of such items excluded from adjusted net profit is determined based on the specific rate of taxes applicable to each item, with the exception for finance charges or income, to which the Italian statutory tax rate of 33% is applied.
Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or U.S. GAAP. Management includes them in order to facilitate a comparison of base business performance across periods and allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models. In addition, management uses segmental adjusted net profit when calculating return on average capital employed (ROACE) by each business segment.

The following is a description of items which are excluded from the calculation of adjusted results.

Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold calculated using the weighted average cost method of inventory accounting.

Special items include certain relevant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-recurring items under such circumstances; or (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past periods or are likely to occur in future ones. As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. In addition gains or losses on the fair value evaluation of derivative financial instruments held for trading purposes and exchange rate differences are excluded from the adjusted net profit of business segments.
Therefore, the adjusted net profit of business segments includes finance charges or income deriving from certain segment-operated assets, i.e., interest income on certain receivable financing and securities related to operations and finance charge pertaining to the accretion of certain provisions recorded on a discounted basis (as in the case of the asset retirement obligations in the Exploration & Production division).
Finance charges or interest income and related taxation effects excluded from the adjusted net profit of the business segments are allocated on the aggregate Corporate and financial companies.

For a reconciliation of adjusted operating profit and adjusted net profit to reported operating profit and reported net profit see tables below.

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Table of Contents
First Quarter 2007   E&P   G&P   R&M   Petrochemicals   Engineering
& Construction
  Other activities   Corporate and financial companies   Impact of
unrealized profit in inventory
  Group
(million euro)  
 
 
 
 
 
 
 
 
Reported operating profit   3,132     1,641     (10 )   115     176     (16 )   (38 )   105     5,105  
Exclusion of inventory holding (gains) losses         40     112     3                             155  
Exclusion of special items:                                                      
of which:                                                      
Non-recurring (income) charges                                                      
Other special (income) charges:         2     18     4           (34 )   3           (7 )
     environmental charges               17                                   17  
     asset impairments                                 3                 3  
     provision for redundancy incentives         2     1     4                 3           10  
     other                                 (37 )               (37 )
Special items of operating profit         2     18     4           (34 )   3           (7 )
Adjusted operating profit   3,132     1,683     120     122     176     (50 )   (35 )   105     5,253  
Net financial (expense) income (*)   (35 )   3                             (101 )         (133 )
Net income from investments (*)   10     115     51           26                       202  
Income taxes (*)   (1,698 )   (642 )   (58 )   (43 )   (57 )         50     (39 )   (2,487 )
Tax rate (%)   54.7     35.6     33.9                                   46.7  
Adjusted net profit   1,409     1,159     113     79     145     (50 )   (86 )   66     2,835  
of which:                                                      
- net profit of minorities                                                   155  
- Eni's adjusted net profit                                                   2,680  
                                                       
Eni's reported net profit                                                   2,588  
Exclusion of inventory holding (gains) losses                                                   97  
Exclusion of special items                                                   (5 )
- non-recurring (income) charges                                                      
- other special (income) charges                                                   (5 )
Eni's adjusted net profit                                                   2,680  
     
(*)   Excluding special items.

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Table of Contents
First Quarter 2006   E&P   G&P   R&M   Petrochemicals   Engineering
& Construction
  Other activities   Corporate and financial companies   Impact of
unrealized profit in inventory
  Group
(million euro)  
 
 
 
 
 
 
 
 
Reported operating profit   4,308     1,199     89     39     78     (65 )   (51 )   (2 )   5,595  
Exclusion of inventory holding (gains) losses         (30 )   (47 )   (17 )                           (94 )
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges                                                      
Other special (income) charges:   (57 )   34     47     1           2     5           32  
     environmental charges         20     44                                   64  
     asset impairments                                 3                 3  
     gains on disposal of assets   (57 )                                             (57 )
     provisions to the reserve for contingencies               1     2                             3  
     provision for redundancy incentives         14     5                       5           24  
     other               (3 )   (1 )         (1 )               (5 )
Special items of operating profit   (57 )   34     47     1           2     5           32  
Adjusted operating profit   4,251     1,203     89     23     78     (63 )   (46 )   (2 )   5,533  
Net financial (expense) income (*)   (17 )   6                             53           42  
Net income from investments (*)   10     137     47           41     5                 240  
Income taxes (*)   (2,149 )   (467 )   (50 )   (7 )   (32           (1 )   1     (2,705 )
Tax rate (%)   50.6     34.7     36.8                                   46.5  
Adjusted net profit   2,095     879     86     16     87     (58 )   6     (1 )   3,110  
of which:                                                      
- net profit of minorities                                                   156  
- Eni's adjusted net profit                                                   2,954  
                                                       
Eni's reported net profit                                                   2,974  
Exclusion of inventory holding (gains) losses                                                   (59 )
Exclusion of special items                                                   39  
- non-recurring (income) charges                                                      
- other special (income) charges                                                   39  
Eni's adjusted net profit                                                   2,954  
     
(*)   Excluding special items.

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Table of Contents
Fourth Quarter 2006   E&P   G&P   R&M   Petrochemicals   Engineering
& Construction
  Other activities   Corporate and financial companies   Impact of
unrealized profit in inventory
  Group
(million euro)  
 
 
 
 
 
 
 
 
Reported operating profit   3,141     1,303     (386 )   72     149     (221 )   (89 )   (12 )   3,957  
Exclusion of inventory holding (gains) losses         (41 )   386     (4 )                           341  
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges               109     13           62                 184  
Other special (income) charges:   54     7     39     73     3     82     36           294  
     environmental charges         2     27                 62     11           102  
     asset impairments   51           13     50     1     12                 127  
     gains on disposal of assets   (7 )                                             (7 )
     provisions to the reserve for contingencies               4     11                             15  
     provision for redundancy incentives   10     15     30     14     2     1     29           101  
     other         (10 )   (35 )   (2 )         7     (4 )         (44 )
Special items of operating profit   54     7     148     86     3     144     36           478  
Adjusted operating profit   3,195     1,269     148     154     152     (77 )   (53 )   (12 )   4,776  
Net financial (expense) income (*)   (22 )   (1 )                     (7 )   87           57  
Net income from investments (*)   (18 )   97     31     1     47     (1 )   1           158  
Income taxes (*)   (1,851 )   (492 )   (64 )   (14 )   (68 )         22     9     (2,458 )
Tax rate (%)   58.7     36.0     35.8                                   49.2  
Adjusted net profit   1,304     873     115     141     131     (85 )   57     (3 )   2,533  
of which:                                                      
- net profit of minorities                                                   178  
- Eni's adjusted net profit                                                   2,355  
                                                       
Eni's reported net profit                                                   1,520  
Exclusion of inventory holding (gains) losses                                                   213  
Exclusion of special items                                                   622  
- non-recurring (income) charges                                                   184  
- other special (income) charges                                                   438  
Eni's adjusted net profit                                                   2,355  
     
(*)   Excluding special items.

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Analysis of special items

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
184     Non-recurring (income) charges                      
294     Other special charges:       32     (7 )   (39 )
102          environmental charges       64     17     (47 )
127          asset impairments       3     3        
(7 )        gains on disposal of assets       (57 )         57  
15          provisions to the reserve for contingencies       3           (3 )
101          provision for redundancy incentives       24     10     (14 )
(44 )        other       (5 )   (37 )   (32 )


         

 

 

478     Special items of operating profit       32     (7 )   (39 )


         

 

 

5     Net financial (expense) income                      


         

 

 

1     Net income from investments                      
      of which:                      
(73 )        gain on Galp Energia SGPS SA (disposal of gas assets to Rede Electrica National)                      


         

 

 

138     Income taxes       7     2     (5 )
      of which:                      
179          wind-fall tax Algeria                      
2          legal proceeding in Venezuela       38           (38 )


         

 

 

622     Total special items of net profit       39     (5 )   (44 )


         

 

 

 

Adjusted net profit by division

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
3,195     Exploration & Production       4,251     3,132     (26.3 )
1,269     Gas & Power       1,203     1,683     39.9  
148     Refining & Marketing       89     120     34.8  
154     Petrochemicals       23     122     430.4  
152     Engineering & Construction       78     176     125.6  
(77 )   Other activities       (63 )   (50 )   (20.6 )
(53 )   Corporate and financial companies       (46 )   (35 )   (23.9 )
(12 )   Impact of unrealized profit in inventory       (2 )   105        
4,776             5,533     5,253     (5.1 )


         

 

 

 

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Table of Contents

Summarized Group balance sheet (a)

Summarized group balance sheet aggregates the amount of assets and liabilities derived from the statutory balance sheet in accordance with functional criteria which consider the enterprise conventionally divided into the three fundamental areas focusing on resource investments, operations and financing. Management believes that this Summarized group balance sheet is useful information in assisting investors to assess Eni’s capital structure and to analyse its sources of funds and investments in fixed assets and working capital. Management uses the Summarized group balance sheet to calculate key ratios such as return on capital employed (ROACE) and the proportion of net borrowings to shareholders’ equity (leverage) intended to evaluate whether Eni’s financing structure is sound and well-balanced.

(million euro)        
    Dec. 31, 2006   Mar. 31, 2007   Change
   
 
 
Fixed assets                  
Property, plant and equipment, net   44,312     44,435     123  
Other tangible assets   629     622     (7 )
Inventories - compulsory stock   1,827     1,711     (116 )
Intangible assets, net   3,753     3,885     1321  
Investments, net   4,246     4,373     127  
Accounts receivable financing and securities related to operations   557     515     (42 )
Net accounts payable in relation to capital expenditure   (1,090 )   (897 )   193  
   

 

 

    54,234     54,644     410  
Net working capital                  
Inventories   4,752     4,888     136  
Trade accounts receivable   15,230     15,006     (224 )
Trade accounts payable   (10,528 )   (9,692 )   836  
Taxes payable and reserve for net deferred income tax liabilities   (5,396 )   (7,306 )   (1,910 )
Reserve for contingencies   (8,614 )   (8,335 )   279  
Other operating assets and liabilities (b)   641     (1,230 )   (589 )
   

 

 

    (5,197 )   (6,669 )   (1,472 )
Employee termination indemnities and other benefits   (1,071 )   (1,032 )   39  
   

 

 

Capital employed, net   47,966     46,943     (1,023 )
   

 

 

Shareholders' equity including minority interests   41,199     43,091     1,892  
   

 

 

Net borrowings   6,767     3,852     (2,915 )
   

 

 

Total liabilities and shareholders' equity   47,966     46,943     (1,023 )
   

 

 

     
(a)   For a reconciliation to the statutory balance sheet see paragraph "Reconciliation of Summarized Group Balance Sheet and Statement of Cash Flows to statutory schemes" pages 77-78 in Eni's Annual Report 2006.
(b)   Include operating financing receivables and securities related to operations for euro 220 million (euro 249 million at December 31, 2006) and securities covering technical reserves of Eni’s insurance activities for euro 451 million (euro 417 million at December 31, 2006). Other current liabilities net increased by euro 589 million compared with December 31, 2006. This increase was due to a euro 575 million loss recognized on the fair value evaluation of certain financial derivatives instruments. The Group entered into such transactions in order to hedge cash flow expected in the 2008-2011 period from the sale of approximately 2% of Eni’s proved hydrocarbon reserves as of 2006 year-end in connection with its purchase of certain oil producing assets and proved and unproved property onshore Congo and in the Gulf of Mexico finalized in February and April 2007, respectively. In light of this, Eni put in place certain forward sale contracts at a fixed price and call and put options with the same date of exercise. These options can be exercised in presence of crude oil market prices higher or lower compared with contractual prices. Gain and losses relating to these cash flow hedges are taken to reserves. This treatment does not apply to the time value component arising from market price fluctuations within the range provided by these call and put options which is recognized in the profit and loss account under the item net financial expenses because the hedging relationship is ineffective.

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Table of Contents

Leverage and net borrowings

Leverage is a measure of a company’s level of indebtedness, calculated as the ratio between net borrowings which is calculated by excluding cash and cash equivalents and certain very liquid assets from financial debt and shareholders’ equity, including minority interests. Management makes use of leverage in order to assess the soundness and efficiency of the Group balance sheet in terms of optimal mix between net borrowings and net equity, and to carry out benchmark analysis with industry standards. In the medium term, management plans to maintain a strong financial structure targeting a level of leverage up to 0.40.

(million euro)        
    Dec. 31, 2006   Mar. 31, 2007   Change
   
 
 
Total debt   11,699     16,470     4,771  
- Short term debt   4,290     9,670     5,380  
- Long term debt   7,409     6,800     (609 )
Cash and cash equivalents   (3,985 )   (6,670 )   (2,738 )
Securities not related to operations   (552 )   (270 )   282  
Non-operating financing receivables (a)   (395 )   (5,625 )   (5,230 )
   

 

 

Net borrowings   6,767     3,852     (2,915 )
   

 

 

Shareholders' equity including minority interest   41,199     43,091     1,892  
Leverage   0.16     0.09     (0.07 )
   

 

 

     
(a)   The increase of euro 5,230 million is mainly referred to the need to collect the necessary funds to participate in a bid to purchase ex-Yukos gas assets.

Changes in shareholders’ equity

(million euro)        
Shareholders' equity at December 31, 2006         41,199
Net profit for the period   2,743      
Reserve for cash flow hedges   (301 )    
Shares repurchased   (203 )    
Issue of ordinary share capital for employee share incentive schemes   8      
Dividends paid by consolidated subsidiaries to shareholders   (3 )    
Effect on equity of the shares repurchased by consolidated subsidiaries (Snam Rete Gas/Saipem)   (140 )    
Exchange differences from translation of financial statements denominated in currencies other than the euro   (223 )    
Other changes   11      
   



Total changes         1,892
   



Shareholders' equity at March 31, 2007         43,091

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Table of Contents

ROACE (Return On Average Capital Employed)

Return on Average Capital Employed for the Group, on an adjusted basis is the return on Group average capital invested, calculated as the ratio between net adjusted profit before minority interests, plus net finance charges on net borrowings, less the related tax effect and net average capital employed. The tax rate applied on finance charges is the Italian statutory tax rate of 33%. The capital invested as of period-end used for the calculation of net average capital invested is obtained by deducting inventory gains or losses as of the period, rectified from the related tax effect.
ROACE by business segment is determined as the ratio between adjusted net profit and net average capital invested pertaining to each business segment and rectifying the net capital invested as of period-end, from net inventory gains or losses (after applying the business segment specific tax rate).

 

(million euro)        









Calculated on a 12-month period ending on   E&P   G&P   R&M   Group
March 31, 2007                









Adjusted net profit   6,593   3,142   656   10,743  
Exclusion of after-tax finance expenses/interest income               50  
Adjusted net profit unlevered   6,593   3,142   656   10,793  
Capital employed, net                  
- at the beginning of period   19,702   17,656   5,556   47,843  
- at the end of period   17,143   18,985   5,830   47,132  
Average capital employed, net   18,423   18,321   5,693   47,488  
ROACE adjusted (%)   35.8   17.2   11.5   22.7  

 

(million euro)        









Calculated on a 12-month period ending on   E&P   G&P   R&M   Group
March 31, 2006                









Adjusted net profit   6,931   2,427   908   10,303  
Exclusion of after-tax finance expenses/interest income               (80 )
Adjusted net profit unlevered   6,931   2,427   908   10,223  
Capital employed, net                  
- at the beginning of period   18,708   18,283   4,247   46,623  
- at the end of period   19,702   17,590   4,950   47,147  
Average capital employed, net   19,205   17,937   4,599   46,885  
ROACE adjusted (%)   36.1   13.5   19.7   21.8  

 

(million euro)        









Calculated on a 12-month period ending on   E&P   G&P   R&M   Group
December 31, 2006                









Adjusted net profit   7,279   2,862   629   11,018  
Exclusion of after-tax finance expenses/interest income               46  
Adjusted net profit unlevered   7,279   2,862   629   11,064  
Capital employed, net                  
- at the beginning of period   20,206   18,978   5,993   49,692  
- at the end of period   18,590   18,864   5,766   47,999  
Average capital employed, net   19,398   18,921   5,880   48,846  
ROACE adjusted (%)   37.5   15.1   10.7   22.7  

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Table of Contents

Summarized Group cash flow statement

Eni’s summarized group cash flow statement derives from the statutory statement of cash flows. It allows to create a link between changes in cash and cash equivalents (deriving from the statutory cash flows statement) occurring from the beginning of period to the end of period and changes in net borrowings (deriving from the summarised cash flow statement) occurring from the beginning of period to the end of period. The measure enabling to make such a link is represented by “free cash flow” which is the cash in excess of capital expenditure needs. Starting from free cash flow it is possible to determine either: (i) changes in cash and cash equivalents for the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to financing activities), shareholders’ equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange differences; (ii) changes in net borrowings for the period by adding/deducting cash flows relating to shareholders’ equity and the effect of changes in consolidation and of exchange differences.

SUMMARIZED GROUP CASH FLOW STATEMENT (1)

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
1,698     Net profit       3,130     2,743     (387 )
      adjustments to reconcile to cash generated from operating profit before changes in working capital:                      
1,568     - amortisation and depreciation and other non monetary items       1,321     1,251     (70 )
(4 )   - net gains on disposal of assets       (63 )   (14 )   49  
2,314     - dividends, interest, taxes and other changes       2,843     2,397     (446 )


         

 

 

5,576     Cash generated from operating profit before changes in working capital       7,231     6,377     (854 )
(847 )   Changes in working capital related to operations       131     445     314  
(2,951 )   Dividends received, taxes paid, interest (paid) received       (1,499 )   (1,259 )   240  


         

 

 

1,778     Net cash provided by operating activities       5,863     5,563     (300 )
(2,944 )   Capital expenditure       (1,340 )   (2,013 )   (673 )
(19 )   Investments       (19 )   (10 )   9  
201     Disposals       85     12     (73 )
407     Other cash flow related to capital expenditure, investments and disposals       (108 )   (152 )   (44 )


         

 

 

(577 )   Free cash flow       4,481     3,400     (1,081 )
                             
(247 )   Borrowings (repayment) of debt related to financing activities       380     (5,035 )   (5,415 )
839     Changes in short and long-term financial debt       (1,851 )   4,887     6,738  
(2,412 )   Dividends paid and changes in minority interests and reserves       (356 )   (445 )   (89 )
(77 )   Effect of changes in consolidation and exchange differences       (30 )   (69 )   (39 )


         

 

 

(2,474 )   NET CASH FLOW FOR THE PERIOD       2,624     2,738     114  


         

 

 

 

CHANGE IN NET BORROWINGS

(million euro)        

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
(577 )   Free cash flow       4,481     3,400     (1,081 )
      Net borrowings of acquired companies                      
      Net borrowings of divested companies       46           (46 )
72     Exchange differences on net borrowings and other changes       13     (40 )   (53 )
(2,412 )   Dividends paid and changes in minority interests and reserves       (356 )   (445 )   (89 )
(2,917 )   CHANGE IN NET BORROWINGS       4,184     2,915     (1,269 )


         

 

 

     
(1)   For a reconciliation of the summarised group cash flow statement to the statutory cash flow statement see 2006 Eni's Annual Report "Reconciliation of summarised group balance sheet and cash flow statement to statutory schemes" pages 79-80.

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Table of Contents

Capital expenditure

Exploration & Production

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
139     Acquisitions of proved and unproved property             73     ..  
139     Italy                   ..  
      North Africa             5     ..  
      West Africa                   ..  
      Rest of world             68     ..  
                             
706     Exploration       173     373     ..  
38     Italy       23     34     47.8  
91     North Africa       48     83     72.9  
366     West Africa       47     68     44.7  
75     North Sea       15     75     ..  
136     Rest of world       40     113     ..  
                             
1,056     Development       777     909     17.0  
133     Italy       85     107     25.9  
209     North Africa       140     188     34.3  
294     West Africa       138     266     92.8  
121     North Sea       94     89     (5.3 )
299     Rest of world       320     259     (19.1 )
36     Other       11     11     ..  
1,937             961     1,366     42.1  

Gas & Power

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
397     Italy       140     154     10.0  
56     Outside Italy       11     67     ..  
453             151     221     46.4  
22     Market       7     5     (28.6 )
      Italy                   ..  
22     Outside Italy       7     5     (28.6 )
54     Distribution       27     25     (7.4 )
287     Transport       91     144     58.2  
253     Italy       87     82     (5.7 )
34     Outside Italy       4     62     ..  
90     Power generation       26     47     80.8  
453             151     221     46.4  

Refining & Marketing

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
241     Italy       79     123     55.7  
31     Outside Italy       16     11     (31.3 )
272             95     134     41.1  
139     Refining and Supply and Logistics       67     104     55.2  
139     Italy       67     104     55.2  
      Outside Italy                   ..  
90     Marketing       25     30     20.0  
59     Italy       9     19     ..  
31     Outside Italy       16     11     (31.3 )
43     Other activities       3           ..  
272             95     134     41.1  

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Table of Contents

Exploration & Production


Daily production of oil and natural gas by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
1,796     Daily production of oil and natural gas (a)   (kboe/d)   1,827     1,734     (5.1 )
232          Italy       247     223     (9.7 )
571          North Africa       541     566     4.6  
372          West Africa       382     337     (11.8 )
291          North Sea       298     287     (3.7 )
330          Rest of world       359     321     (10.6 )
159.2     Oil and natural gas production sold (a)   (mmboe)   159.5     150.1     (5.9 )

Daily production of liquids by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
1,079     Production of liquids (a)   (kbbl/d)   1,143     1,030     (9.9 )
80          Italy       82     77     (6.1 )
334          North Africa       325     328     0.9  
315          West Africa       339     288     (15.0 )
181          North Sea       188     170     (9.6 )
169          Rest of world       209     167     (20.1 )

Daily production of natural gas by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
4,132     Production of natural gas (a)   (mmcf/d)   3,920     4,061     3.6  
883          Italy       954     848     (11.1 )
1,377          North Africa       1,236     1,377     11.4  
318          West Africa       247     283     14.3  
636          North Sea       636     671     5.6  
918          Rest of world       847     882     4.2  
     
(a)   Includes Eni's share of production of equity-accounted entities.

- 26 -


Table of Contents

Gas & Power


Natural gas sales

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
14.09     Italy to third parties (*)       17.47     15.41     (11.8 )
3.45     Wholesalers (selling companies)       5.06     4.62     (8.7 )
0.56     Gas release       0.59     0.49     (16.9 )
10.08     End Customers       11.82     10.30     (12.9 )
3.50          Industries       3.80     3.33     (12.4 )
4.30          Power generation       4.27     3.93     (8.0 )
2.28          Residential       3.75     3.04     (18.9 )
1.55     Own consumption (*)       1.47     1.39     (5.4 )
8.14     Rest of Europe (*)       8.57     7.90     (7.8 )
0.12     Outside Europe       0.16     0.10     (37.5 )
23.90     Total sales to third parties and own consumption       27.67     24.80     (10.4 )
1.97     Sales of Eni's affiliates (net to Eni)       2.41     2.27     (5.8 )
0.01          Italy (*)       0.01     0.01        
1.83          Rest of Europe (*)       2.33     2.10     (9.9 )
0.13          Outside Europe       0.07     0.16     ..  
25.87     Total sales and own consumption (G&P)       30.08     27.07     (10.0 )
1.06     Upstream in Europe       1.12     1.07     (4.5 )
26.93     Worldwide sales       31.20     28.14     (9.8 )
26.68     Total sales in Europe       30.97     27.88     (10.0 )
25.62     G&P in Europe (*)       29.85     26.81     (10.2 )
1.06     Upstream in Europe       1.12     1.07     (4.5 )
     
(*)   Market sector denoted with an asterisk are included within "Total sales in Europe".

- 27 -


Table of Contents

PRESS RELEASE

 

Eni S.p.A.
Registered Office: Piazzale Enrico Mattei, No. 1, Rome - Italy
Company Share capital euro 4,005,358,876.00 fully paid up
Rome Companies Register, Tax Identification Number 00484960588
VAT Number 00905811006, R.E.A. Rome No. 756453

Ordinary and Extraordinary Shareholders’ Meeting Resolutions

 

Eni S.p.A. Ordinary and Extraordinary Shareholders’ Meeting held on May 24, 2007 resolved to:

 


Table of Contents

Eni 2006 Financial Statements and Sustainability Report

Eni S.p.A. Financial Statements at December 31, 2006 approved by the Shareholders’ Meeting, Eni consolidated Financial Statements at December 31, 2006, Eni Portugal Investment S.p.A. and Società Finanziaria Eni - Enifin S.p.A. financial statements at December 31, 2006 are available at Eni S.p.A. Registered Office and the Borsa Italiana S.p.A. (the Italian Stock Exchange: www.borsaitaliana.it).

The minutes of the Meeting will be available within June 8, 2007 at Eni S.p.A. Registered Office and the Borsa Italiana S.p.A. (the Italian Stock Exchange: www.borsaitaliana.it).

It is also available at Eni S.p.A. Registered Office and the Borsa Italiana S.p.A. (the Italian Stock Exchange: www.borsaitaliana.it) the Sustainability Report 2006.

The above-mentioned documents are available also on www.eni.it and may be requested by e-mail at segreteriasocietaria.azionisti@eni.it or by calling the Toll-Free number 800 940 924 for calls from Italy and 800 11 22 34 56 for calls from outside Italy.

Payment of Year 2006 final Dividend

Eni S.p.A. Shareholders’ Meeting resolved to pay final dividends as from June 21, 2007, coupon No. 8, being the ex-dividend date June 18, 2007. Therefore, as of this last date, Eni shares will be traded without the right to the payment of 2006 final dividend.

In order to exercise the rights incorporated in the shares owned, Shareholders whose shares are not yet in uncertificated form shall previously deliver said shares to a financial intermediary for their deposit with Monte Titoli S.p.A. (the Italian Securities Register Centre) and their subsequent dematerialisation.

The payment of dividends to Beneficial Owners of ADRs, each of them representing two Eni shares, listed on the New York Stock Exchange, will be executed through JPMorgan Chase Bank, N.A..

 

Company contacts:

Press Office: Phone +39 02.52031875 - +39 06.5982398
Switchboard: +39-0659821

ufficio.stampa@eni.it
segreteriasocietaria.azionisti@eni.it
investor.relations@eni.it 

Website: www.eni.it

 


Table of Contents

 

San Donato Milanese (Milan) - May 28, 2007 - As part of the inquiry launched last year by the Public Prosecutor Office of Milan on the instruments to assess the natural gas transport and distribution used in Italy by companies operating in the sector, today the Italian Fiscal Police sequestrated documents dating from 2003 belonging to various companies, among them are some Eni’s companies.

Under investigation are the so-called venturimeters, instruments always used in Italy and abroad and that do not have any impact on the assessments connected with costumers bills.

With regard to Eni Group, the companies involved are Snam Rete Gas and Italgas. Paolo Scaroni, as legal representative of the parent company Eni SpA, and other managers are under inquiry.

 

Company contacts:

Press Office: Phone +39 02.52031875 - +39 06.5982398
Switchboard: +39-0659821

ufficio.stampa@eni.it
segreteriasocietaria.azionisti@eni.it
investor.relations@eni.it 

Website: www.eni.it

 


Table of Contents

 

San Donato Milanese (Milan), May 28, 2007 - Inquiry by the Public Prosecutor Office of Milan, Paolo Scaroni, Eni’s CEO commented:

"We are confident: the measurements under investigation receive a special attention from all the companies operating in the gas market in Italy and abroad. In fact, I myself, as soon as I arrived in Eni, gave mandate to specialized international consultants to undertake an assessment of this gas measurements procedures.

Furthermore, we are referring to measurements on non-booked gas, which is the difference between gas that Eni buys from its suppliers and the one that Eni then sells to distributors. This difference represents so far, for our company, a net loss of some hundred million cubic meters of gas per year. It’s important for me to remind that gas measurements for the retail market are carried out in strict compliance with the indications given by the Authority for Energy and Gas and by the competent offices of the Ministry of Economic Development".

 

 

Company contacts:

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Switchboard: +39-0659821

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Eni completes acquisition of Maurel & Prom’s assets in Congo

San Donato Milanese (Milan), May 30, 2007 - Eni announces that it has today completed the acquisition of Maurel & Prom assets in the Republic of Congo. Eni has obtained the operatorship of the M’Boundi (Eni equity 43.1%) and Kouakouala "A" (66.67%) concessions and of the Le Kouilou exploration permit (48%).

Through the development of the M’Boundi field, which has oil-in-place estimated at 1.4 billion barrels and 2P reserves amounting to 320 million barrels, Eni’s equity production in Congo will rise from 67,000 barrels per day (bpd) in 2006 to approximately 100,000 bpd in 2010.

In the development of these new fields, Eni intends to create important synergies with existing activities in the country. By adopting the most advanced technologies, such as an intense drilling programme of water injection wells, Eni also aims to improve the oil recovery factor of the acquired fields and to develop the exploration potential of Le Kouilou permit.

As part of its sustainability strategy, Eni has also signed a "Protocole d’Accord" with the Republic of Congo for doubling the volumes of power of the Djeno power station by installing a second 25-MW turbo-generator to be supplied with associated gas produced from the M’Boundi field. This project aims at increasing the power and reliability of the local electricity system, needed for the country’s industrial development and social improvement.

 

 


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Eni has been active in Congo in exploration and development activities since 1968 and has invested some 4 billion dollars to 2006.

 

 

Company contacts:

Press Office: Phone +39 02.52031875 - +39 06.5982398
Switchboard: +39-0659821

ufficio.stampa@eni.it
segreteriasocietaria.azionisti@eni.it
investor.relations@eni.it 

Website: www.eni.it

 


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Eni: Agreement completed with Burren Energy

 

San Donato Milanese (Milan), May 30, 2007 - As part of the acquisition of the Maurel & Prom assets in the Republic of Congo, Eni announces that it has today completed its agreement with Burren Energy. Under this agreement Eni assigned to Burren a participating interest of 5.5% and 2% in the M’Boundi concession and Le Kouilou exploration permit, respectively, at the same economic terms and conditions as the acquisition from Maurel & Prom.

Eni maintains the operatorship of the M’Boundi (43.1%) and Kouakoula "A" (66.67%) concessions and Le Kouilou exploration permit (48.0%).

 

 

Company contacts:

Press Office: Phone +39 02.52031875 - +39 06.5982398
Switchboard: +39-0659821

ufficio.stampa@eni.it
segreteriasocietaria.azionisti@eni.it
investor.relations@eni.it 

Website: www.eni.it

 


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Eni Board of Directors

 

San Donato Milanese (Milan), May 31, 2007 - An extra-ordinary Board of Directors was held today in Rome to examine the main points of the provision by the Power of attorney of the Republic of Milan (Procura della Repubblica di Milano) on gas measurements. In particular, the Board has examined the explanations given by the management of the companies and executive structures involved in gas transport, distribution and sale.

Taking note of the correcteness of the behaviour of Eni’s companies and executive structures involved in gas transport, distribution and sale, the Board has given mandate to its lawyers to supply all available information and to cooperate fully with the Prosecutor Office.

 

 

Company contacts:

Press Office: Phone +39 02.52031875 - +39 06.5982398
Switchboard: +39-0659821

ufficio.stampa@eni.it
segreteriasocietaria.azionisti@eni.it
investor.relations@eni.it 

Website: www.eni.it

 


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Contents

 

 

 

 

 

 

Eni’s Fact Book is a supplement to Eni’s Annual Report designed to provide supplemental financial and operating information.
It contains certain forward-looking statements in particular under the section “Outlook” regarding capital expenditure, development andmanagement of oil and gas resources, dividends, share repurchases, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets, and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors and other factors discussed elsewhere in this document.




April 30, 2007

 


Table of Contents
Eni   2   Activities Strategies Objectives
    5   Main data
         
Exploration & Production   10   Strategies
    10   2006 Highlights
    13   Activity Areas
    35   Main data
         
Gas & Power   44   Strategies
    45   2006 Highlights
    46   The Gas System
    47   Activities
    58   Main data
         
Refining & Marketing   61   Strategies
    62   2006 Highlights
    63   Activities
    70   Main data
         
Engineering & Construction   74   Strategies
    75   Business areas
    80   Main data
         
Technological Innovation   82   Technological innovation
         
Tables   87   Financial data
    102   Employees
    103   Supplemental oil and gas information
    121   Energy conversion table
    122   Quarterly information

 

Abbreviations   /d per day   LNG liquefied natural gas
    /y per year   LPG liquefied petroleum gas
    bbbbl billion barrels   kbbl thousand barrels
    bbls barrels   kboe thousand barrels of oil equivalent
    bboe billion barrels of oil equivalent   km kilometers
    bcf billion cubic feet   ktonnes thousand tonnes
    bcm billion cubic meters   mmbbl million barrels
    boe barrels of oil equivalent   mmboe million barrels of oil equivalent
    EPC Engineering Procurement Construction   mmcf million cubic feet
    EPIC Engineering Procurement Installation Construction   mmcm million cubic meters
    FPSO Floating Production Storage and Offloading system   mmtonnes million tonnes
    FSO Floating Storage and Offloading System   no. number
    GWh gigawatthour   NGL Natural Gas Liquids
          PSA Production Sharing Agreement
          TWh terawatthour

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ENI FACT BOOK / ENI

Activities Strategies
Objectives
   
     
     
     
Eni is a major integrated energy company, committed to growth in the activities of finding, producing, transporting, transforming and marketing oil and gas.

In Exploration & Production, Eni boasts strong positions in some of the fastest growing oil and gas basins in the world such as the Caspian Region, North and West Africa.
The quality of our assets, long-standing relationships with key host countries, and a strong pipeline of capital projects and investment opportunities will enable Eni to deliver industry-leading growth in both the short term and the long term.

Eni Gas & Power division covers all phases of the gas value chain: supply, transport, distribution and marketing, resulting in a fully integrated business model. A significant installed power generation capacity enables Eni to extract further value from gas, diversifying its commercial outlets. The main feature of the Gas & Power division is its ability to generate a steady stream of earnings and cash flow leveraging on its unparalleled asset base. Eni boasts market leadership in Europe owing to a unique competitive position thanks to gas availability under long-term supply contracts and equity gas, access to infrastructure, long-term relationships with key producing countries, market knowledge and a wide portfolio of clients. These assets provide Eni with a unique platform for growth. Integration with upstream operations provides the Group with the ability to monetize its equity gas reserves and to pursue opportunities arising in the gas market.
Eni is leader in the refining business and in the marketing of refined products in Italy and holds solid positions in the marketing of refined products in certain
  selected European countries. Eni’s refining and marketing operations are efficiently integrated also with the support of an array of valuable logistic assets, as to maximize cost economies and returns on capital employed. Integration of Eni refineries with upstream operations further strengthens the competitive positioning of the Refining & Marketing Division.
The significant presence in engineering and oilfield services provides Eni with the necessary competence and, expertise coupled with access to engineering skills and technologies to design and execute world scale projects, representing a key elements supporting Eni plans of growth and innovation.
This business mix is unique among integrated oil and gas companies. The relevant weight of the downstream gas business ensures Eni a stable, robust stream of earnings and cash flow, virtually independent of energy price movements, thus counterbalancing the fluctuations of the oil cycle and the higher riskiness of the upstream business. The same applies to the downstream oil business.

Eni key objectives are to deliver superior growth and attractive shareholder returns over the long term, leveraging on the quality of its assets and its strengths. Eni’s strategy is consistent with these goals, and relies upon the following guidelines:
  • leverage on its asset portfolio and execution capabilities;
  • allocate the cash generated from operations to capital expenditure to drive long-term organic growth and to an attractive and sustainable flow of dividends;
  • use cash in excess of capital expenditure and dividend needs to continue the programme of share repurchase and to maintain a solid financial structure;

 

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ENI FACT BOOK / ENI

  • apply a tight financial discipline to investment decisions;
  • accomplish continued operating efficiency and effectiveness;
  • manage risks;
  • devote significant resources to technological innovation in order to create and maintain competitive advantages;
  • promote the sustainability of the business model.

Over the next four years, Eni expects to invest approximately euro 44.6 billion in its businesses to support continued growth also beyond 2010, featuring the largest investment program in Eni history.
The significant amount of cash flow generated from operations will enable Eni to finance its capital expenditure programme and to distribute shareholders an attractive and sustainable flow of dividends. Excess cash will be allocated to continuing share repurchase and to maintain a sound balance sheet. In particular, management expects that Eni’s free cash flow1 will allow to sustain the current flow of dividends in real terms, even with a scenario of 40 $/bbl Brent.



BUSINESS STRATEGIES

Exploration & Production
In the Exploration & Production business, Eni intends to deliver strong oil and gas production growth, targeting a production level of 2 million boepd by 2010, corresponding to a compound average growth rate of 3% from 2007 to 2010. The growth options we are presently pursuing with our partner Gazprom may potentially accelerate the achievement of our growth targets.

  Eni will maintain a strong focus on exploration activities. Investments are expected to be concentrated on well established areas of presence, where availability of production facilities and existing competencies will enable Eni to readily put in production discovered resources, capturing synergies. On the other hand, we expect to selectively pursue high risk/high reward opportunities arising from expansion in areas with high mineral potential. Leveraging on the access to new reserves and on the mineral potential of core assets, Eni expects to fully replace produced reserves trough organic additions. We will continue our commitment in expanding the LNG business in a global scale in order to monetize our large gas reserve base. This will be achieved by implementing significant capital expenditure in order to develop new gas reserves to ensure supplies to liquefaction plants and to build new liquefaction capacity.

Gas & Power
Our key objective in the Gas & Power division is to deliver a level of free cash flow of euro 2.1 billion in 2010, with an average growth rate of approximately 3%.
This target will be achieved by implementing our strategy focused on growing our market share in key European markets, preserving our domestic natural gas business, effectively managing regulated business and the power generation business, and expanding LNG sales. In strengthening our market leadership in Europe, we will leverage on our competitive advantages ensured by gas availability – both equity and purchased under long term supply contracts – access to infrastructure, an adequate regasification capacity, long-standing relationships with natural gas producing countries, a large customer base, and market knowledge.

 

     
(1)   Cash from operations exceeding finance needs for investments.

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ENI FACT BOOK / ENI

 

The target of maintaining sales volumes on the domestic market will be achieved thanks to the support of an effective commercial policy, enhanced by the expected launch of the dual offer of gas and electricity.
By 2010 Eni will be selling some 105 bcm worldwide, with international sales expected to grow by a solid 10% per year on average.

Refining & Marketing
Eni’s key objective is to significantly increase profitability in the Refining & Marketing business. In pursuing this, Eni intends to enhance its refining activity by means of a huge investment program aiming at capturing market opportunities in terms of demand trends, also in connection with adoption of increasingly strict environmental requirements, and relative abundance of heavy and non-conventional crude. Planned actions are intended to boost refinery conversion rate and flexibility in order to produce higher-value products and to process low-quality crude that is typically discounted in the market-place, and to lower operating costs. In Marketing, we aim to extract full value from our retail business in Italy through a selective investment program, customer-focused marketing initiatives, effective differentiation of pricing, an improved premium-products offer, and operating efficiencies. We plan to selectively develop our presence outside Italy, aiming at strengthening our competitive position in target European markets, leveraging on
  synergies deriving from the proximity to Eni’s production and logistic facilities.

Engineering & Construction
Saipem aims at capturing opportunities arising from a growing market, acquiring large projects in complex areas and supporting Eni’s investment plans. In order to achieve this, Saipem will leverage on its strong competitive position, enhanced by integration with Snamprogetti, and an important investment program intended to further expand the geographical reach and operational features of its world-class fleet.

Technological innovation
Our commitment in technological research and innovation underscores a fundamental belief that technology is key to acquiring and preserving competitive advantages over the long term and promoting sustainable growth. Over the next four years, we plan to invest approximately euro 1.5 billion to support these activities. The main lines of research under development pertain primarily to reduce costs to find and recover hydrocarbons, upgrade heavy oils, monetize stranded gas and protect the environment.
In particular we are moving forward on our breakthrough technologies: EST (Eni Slurry Technology) for the full exploitation of the heavy barrel, TAP (gas transportation at high pressure) and GTL (gas-to-liquids) for gas monetization.

 

Key medium-term targets announced to investors 2006 2010
E&P    
     Oil and gas production 1.77 mmboe/d >2 mmboe/d - c.a.g.r. 3% (Brent 42 $/bl al 2010)
     Reserve replacement ratio 65% >100% on average in the next four-year period (Brent 42 $/bbl at 2010)
     Sales of LNG 9.9 bcm ~13 bcm
G&P    
     Worldwide gas sales (1) 97.5 bcm >105 bcm - c.a.g.r. 10% in international sales
     Power generation capacity 4.9 GW 5.5 GW
     Free cash flow euro 1.9 bn euro 2.1 bn
R&M    
     Overall index of wholly-owned refineries conversion capacity 57% 58%
     Refinery throughputs on own account 38.0 mmtonnes 40.2 mmtonnes
     Sales of refined products in Europe 15.8 bn liters 17.4 bn liters
Allocation of cash provided by operating activities    
     Capital expenditure euro 32.2 bn four-year period 2006-2009 euro 44.6 bn four-year period 2007-2010
     Dividend euro 1.25 per share sustainable in the next four-year period 2007-2010
Efficiency program   ~euro 1 bn of net benefit expected in 2010
     
(1)   Include upstream sales in Europe.

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ENI FACT BOOK / IENI

Main data

Key financial data  

Italian GAAP

 

IFRS

   
 

(million euro)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Net sales from operations       31,359     28,341     31,008     47,938     49,272     47,922     51,487     57,545     73,728     86,105  
Operating profit (1)       5,345     3,810     5,480     10,772     10,313     8,502     9,517     12,399     16,827     19,327  
     Exploration & Production       2,590     594     2,834     6,603     5,984     5,175     5,746     8,185     12,574     15,580  
     Gas & Power       2,012     2,513     2,580     3,178     3,672     3,244     3,627     3,428     3,321     3,802  
     Refining & Marketing       578     730     478     986     985     321     583     1,080     1,857     319  
     Petrochemicals       187     -     (362 )   4     (415 )   (126 )   (176 )   320     202     172  
     Engineering & Construction       169     198     149     144     255     298     311     203     307     505  
     Other activities                                     (214 )   (293 )   (395 )   (902 )   (622 )
     Corporate and financial companies       (138 )   (168 )   (199 )   (143 )   (168 )   (196 )   (281 )   (363 )   (391 )   (296 )
     Unrealized profit in inventory                                                 (59 )   (141 )   (133 )
     Activities to be divested       (53 )   (57 )                                                
Adjusted operating profit                               10,482     8,959     9,958     12,582     17,558     20,490  
Net profit       2,643     2,328     2,857     5,771     7,751     4,593     5,585     7,059     8,788     9,217  
Adjusted net profit                               5,757     4,923     5,096     6,645     9,251     10,412  
Net cash provided by operating activities       6,515     6,864     8,248     10,583     8,084     10,578     10,827     12,500     14,936     17,001  
Capital expenditure and investments       4,362     5,589     5,597     9,815     11,270     9,414     13,057     7,815     7,560     7,928  
     Capital expenditure       4,169     5,152     5,483     5,431     6,606     8,048     8,802     7,499     7,414     7,833  
     Investments       193     437     114     4,384     4,664     1,366     4,255     316     146     95  
Shareholders’ equity including minority interest       16,244     17,390     19,749     24,073     29,189     28,351     28,318     35,540     39,217     41,199  
Net borrowing       8,050     7,070     6,267     7,742     10,104     11,141     13,543     10,443     10,475     6,767  
Net capital employed (1)       24,294     24,460     26,016     31,815     39,293     39,492     41,861     45,983     49,692     47,966  
     Exploration & Production       6,469     6,862     9,279     12,646     18,252     17,318     17,340     17,937     20,196     18,590  
     Gas & Power       8,518     8,289     8,481     10,721     12,777     12,488     15,617     18,387     18,978     18,906  
     Refining & Marketing       4,071     4,186     4,028     4,563     4,476     5,093     5,089     5,081     5,993     5,631  
     Petrochemicals       3,099     2,956     2,604     2,581     1,075     2,130     1,821     2,076     2,018     1,953  
     Engineering & Construction       195     392     1,103     1,395     1,635     2,335     2,119     2,403     2,844     3,399  
     Corporate and financial companies
     and other activities
      1,942     1,775     521     (91 )   1,078     128     (125 )   277     2     (95 )
     Unrealized profit in inventory                                                 (178 )   (339 )   (418 )
Return On Average Capital Employed   (%)                                                            
     Reported       12.2     10.7     12.5     21.5     23.9     13.7     15.6     16.6     19.5     20.3  
     Adjusted                                                 15.9     20.5     22.7  
Leverage       0.5     0.41     0.32     0.32     0.35     0.39     0.48     0.29     0.27     0.16  
     
(1)   From January 1, 2006 Eni’s subsidiaries operating in diversified sectors (such as real estate services, insurance and financing intermediation, R&D and training services) are reported in the aggregate “Corporate and financing companies” with exception of Tecnomare which is reported in the Exploration & Production division (previously all these diversified activities were reported in the aggregate “Other activities”). The “Other activities” aggregate includes only Syndial SpA, a subsidiary which runs minor petrochemical activities and reclamation and decommissioning activities pertaining to certain business which Eni exited in past years. In order to allow for comparison, 2005 data has been reclassified accordingly. Previous years data has not been reclassified.

 

Key market indicators      

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Average price of Brent dated crude oil (1)       19.10   12.74   17.87   28.39   24.46   24.98   28.84   38.22   54.38   65.14
Average EUR/USD exchange rate (2)       1.137   1.115   1.067   0.924   0.896   0.946   1.131   1.244   1.244   1.256
Average price in euro of Brent dated crude oil       16.80   11.43   16.75   30.73   27.30   26.41   25.50   30.72   43.71   51.86
Average European refining margin (3)       1.86   1.99   1.21   3.9   1.97   0.80   2.65   4.35   5.78   3.79
Euribor - three-month euro rate   (%)   6.9   5.0   3.0   4.4   4.3   3.3   2.3   2.1   2.2   3.1
     
(1)   In US dollars per barrel. Source: Platt’s Oilgram.
(2)   Source: ECB.
(3)   In US dollars per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations based on Platt’s Oilgram data.

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Selected operating data      

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Exploration & Production                                            
Proved reserves of hydrocarbons at period end   (mmboe)   5,073   5,255   5,534   6,008   6,929   7,030   7,272   7,218   6,837   6,436
Reserve life index   (year)   13.6   13.4   14.0   14.0   13.7   13.2   12.7   12.1   10.8   10.0
Daily production of hydrocarbons   (kboe/d)   1,021   1,038   1,064   1,187   1,369   1,472   1,562   1,624   1,737   1,770
Gas & Power                                            
Sales of natural gas to third parties   (bcm)   55.94   58.41   62.92   62.63   63.72   64.12   69.49   72.79   77.08   79.63
Own consumption of natural gas   (bcm)               2.00   2.00   2.02   1.90   3.70   5.54   6.13
Sales to third parties and own consumption   (bcm)               64.63   65.72   66.14   71.39   76.49   82.62   85.76
Sales of natural gas of affiliates and companies (Eni’s share)   (bcm)   0.13   0.16   0.16   0.87   1.38   2.40   6.94   5.84   7.08   7.65
Total sales and own consumption of natural gas (G&P)   (bcm)   56.07   58.57   63.08   65.50   67.10   68.54   78.33   82.33   89.70   93.41
Upstream in Europe (1)   (bcm)                               4.70   4.51   4.07
Worldwide   (bcm)   56.07   58.57   63.08   65.50   67.10   68.54   78.33   87.03   94.21   97.48
Natural gas transported on behalf of third parties in Italy   (bcm)   4.35   6.07   6.90   9.45   11.41   19.11   24.63   28.26   30.22   30.90
Electricity production sold   (TWh)               4.77   4.99   5.00   5.55   13.85   22.77   24.82
Refining & Marketing                                            
Throughputs on own account   (mmtonnes)   38.60   42.33   40.65   41.27   39.99   37.73   35.43   37.69   38.79   38.04
Balanced capacity of wholly-owned refineries at period end   (kbbl/d)   664   664   664   664   664   504   504   504   524   534
Utilization rate of balanced capacity of wholly-owned refineries   (%)   94   103   96   99   97   99   100   100   100   100
Sales of refined products   (mmtonnes)   51.60   54.19   51.82   53.46   53.24   52.24   50.43   53.54   51.63   51.13
Service stations at period end (in Italy and outside Italy)   (units)   12,756   12,984   12,489   12,085   11,707   10,762   10,647   9,140   6,282   6,294
Average throughput per service station (in Italy and outside Italy)   (kliters/y)   1,463   1,512   1,543   1,555   1,621   1,674   1,771   1,970   1,926   2,470
Engineering & Construction                                            
Orders acquired   (euro million)   3,865   3,248   2,600   4,726   3,716   7,852   5,876   5,784   8,395   11,172
Order backlog at period end   (euro million)   5,180   4,934   4,439   6,638   6,937   10,065   9,405   8,521   10,122   13,191
Employees at period end   (units)   80,178   78,906   72,023   69,969   72,405   80,655   76,521   70,348   72,258   73,572
     
(1)   Does not include Eni’s share of sales made by Nigeria LNG (Eni’s share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006 respectively.

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ENI FACT BOOK / ENI

Share data  

Italian GAAP

 

IFRS

   
 

     

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Net profit (1)   (euro)   0.66   0.58   0.71   1.44   1.98   1.20   1.48   1.87   2.34   2.49
Dividend   (euro)   0.289   0.310   0.362   0.424   0.750   0.750   0.750   0.90   1.10   1.25
Dividend pertaining to the year (2)   (euro million)   1,157   1,239   1,446   1,664   2,876   2,833   2,828   3,384   4,086   4,594
Cash flow   (euro)   1.63   1.72   2.06   2.65   2.07   2.76   2.87   3.31   3.97   4.59
Dividend yield (3)   (%)   2.8   2.9   3.4   3.2   5.6   5.2   5.1   4.9   4.7   5.0
Net profit per ADR (4)   ($)   1.44   1.36   1.43   2.71   3.52   2.52   3.72   5.06   5.81   6.26
Dividend per ADR (4)   ($)   0.63   0.64   0.47   0.72   1.48   1.71   1.83   2.17   2.63   3.14
Cash flow per ADR (4)   ($)   3.55   4.02   4.16   4.98   3.75   5.79   7.22   8.96   9.40   11.53
Dividend yield per ADR (3)   (%)   2.8   2.6   3.2   3.0   6.2   5.8   5   5.0   4.70   5.0
Pay-out   (%)   44   53   51   29   37   62   51   48   46.00   50
Number of shares at December 31 representing share capital   (million)   3,999.6   4,000.1   4,001.1   4,001.1   4,001.3   4,001.8   4,002.9   4,004.4   4,005.4   4,005.4
Average number of share outstanding in the year (5) (fully diluted)   (million)   3,999.6   4,000.1   4,001.3   3,995.1   3,911.9   3,826.9   3,778.4   3,771.7   3,763.4   3,701.3
TSR   (%)   32.8   10.1   (0.4 ) 29.2   6.0   13.1   4.3   28.5   35.3   14.8
     
(1)   Calculated on the average number of Eni shares outstanding during the year.
(2)   Amounts due on the payment of the balance of 2006 dividend are estimated.
(3)   Ratio between dividend of the year and average share price in December.
(4)   One ADR represents 2 shares. Net profit, dividends and cash flow are converted at the average rate of the year (1 EUR=1.256 USD as of 2006). Dividends of 1997-2005 were converted at the Noon Buying Rate of the pay-out date.
(5)   Calculated by excluding own shares in portfolio.

 

Share information      

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Share price - Milan Stock Exchange                                            
High   (euro)   11.36   13.80   12.60   14.50   15.60   17.15   15.75   18.75   24.96   25.73
Low   (euro)   8.06   9.19   10.18   9.54   11.56   12.94   11.88   14.72   17.93   21.82
Average   (euro)   9.79   11.28   11.40   11.78   14.10   15.29   13.64   16.94   21.60   23.83
End of the period   (euro)   10.43   11.21   10.88   13.64   14.05   15.15   14.96   18.42   23.43   25.48
ADR price (1) - New York Stock Exchange                                            
High   ($)   63.13   73.50   69.00   64.88   69.70   82.11   94.98   126.45   151.35   67.69
Low   ($)   48.13   50.50   52.38   46.56   52.50   60.90   66.15   92.35   118.50   54.65
Average   ($)   55.62   63.04   60.94   54.18   63.22   72.20   77.44   105.60   134.02   59.97
End of the period   ($)   57.06   67.75   55.13   64.31   61.96   78.49   94.98   125.84   139.46   67.28
Average daily exchanged shares   (million share)   7.9   11.1   12.3   17.3   17.4   19.4   22.0   20.0   28.5   26.2
Value   (euro million)   78.8   126.0   141.0   203.9   245.0   295.4   298.5   338.7   620.7   619.1
Number of shares outstanding at period end (2)   (million)   3,999.6   4,000.1   4,001.1   3,956.7   3,846.9   3,795.1   3,772.3   3,770.0   3,727.3   3,680.4
Market capitalization (3)                                            
EUR   (billion)   41.7   44.8   43.5   54   54   57.5   56.4   69.4   87.3   93.8
USD   (billion)   45.5   52.5   44   50.7   48.1   60.4   71.1   94.9   104.0   117.8
     
(1)   Effective January 10, 2006 a 5:2 stock split was made.
(2)   Excluding treasury shares.
(3)   Number of outstanding shares by reference price at period end.

 

Data on Eni share placements          

1995

 

1996

 

1997

 

1998

 

2001

Offer price   (euro/share)   5.42   7.40   9.90   11.80   13.60
Number of share placed   (million)   601.9   647.5   728.4   608.1   200.1
of which through bonus shares   (million)       1.9   15.0   24.4   39.6
Percentage of share capital (1)   (%)   15.0   16.2   18.2   15.2   5.0
Proceeds   (euro million)   3,254   4,596   6,869   6,714   2,721
     
(1)   Refers to share capital at December 31, 2006.

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ENI FACT BOOK / ENI

 

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ENI FACT BOOK / EXPLORATION & PRODUCTION

  Key performance indicators  

2004

 

2005

   

2006

 
  Net sales from operations (a)  

(million euro)

 

15,346

 

22,531

   

27,173

 
  Operating profit      

8,185

 

12,592

   

15,580

 
  Adjusted operating profit      

8,202

 

12,903

   

15,763

 
  Adjusted net profit      

4,033

 

6,186

   

7,279

 
  Capital expenditure      

4,853

 

4,965

   

5,203

 
  of which: exploration (b)      

499

 

656

   

1,348

 
  Capital employed, net      

17,937

 

20,206

   

18,590

 
  ROACE adjusted  

(%)

 

22.7

 

32.4

   

37.5

 
  Average realizations                    
  - Liquids  

($/bbl)

 

34.73

 

49.09

   

60.09

 
  - Natural gas  

($/mmcf)

 

3.90

 

4.50

   

5.30

 
  - Total hydrocarbons  

($/boe)

 

30.40

 

41.06

   

48.87

 
  Production                    
  - Liquids  

(kbbl/d)

 

1,034

 

1,111

   

1,079

 
  - Natural gas  

(mmcf/d)

 

3,387

 

3,595

   

3,966

 
  - Total hydrocarbons  

(kboe/d)

 

1,624

 

1,737

   

1,770

 
  Net proved reserves                    
  - Liquids  

(mmbbl)

 

4,008

 

3,773

   

3,481

 
  - Natural gas  

(bcf)

 

18,435

 

17,591

   

16,965

 
  - Total hydrocarbons  

(mmboe)

 

7,218

 

6,837

   

6,436

 
  Reserve life index  

(year)

 

12.1

 

10.8

   

10.0

 
  Proved reserve replacement ratio  

(%)

 

91

 

40

   

65

 
  Employees at year end  

(unit)

 

7,477

 

8,030

   

8,336

 
       
  (a)   Before elimination of intersegment sales.
  (b)   Includes exploration bonus.

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ENI FACT BOOK / EXPLORATION & PRODUCTION

STRATEGIES
In Exploration & Production, Eni boasts strong positions in some of the fastest growing oil and gas basins in the world such as the Caspian Region, North and West Africa. The quality of our assets, long-standing relationships with key host countries, and a strong pipeline of capital projects and investment opportunities will enable Eni to deliver industry-leading growth in both the short and the long term. Consistent with this goal, strategies for our global exploration, development and production operations have remained basically unchanged for many years to date and feature as follows:

In order to carry out these fundamental strategies, Eni intends to invest approximately euro 30.6 billion addressed to exploration initiatives and reserve development over the next four-year period.

2006 Highlights

In February 2007, Eni purchased exploration and production onshore activities operated by Maurel & Prom in Congo, entailing a cash consideration of $1.4 billion. This deal is consistent with Eni’s strategy of purchasing proved and unproved reserves and producing assets in legacy countries where Eni can achieve synergies leveraging on own competencies and the availability of facilities. This transaction is subject to approval by the Congolese Authorities.

In 2006 adjusted net profit was euro 7,279 million, up euro 1,093 million from a year ago (+17.7%), reflecting a better operating profit as a result of higher oil and natural gas realizations in dollars combined with increased production volumes sold. These positives were offset in part by higher operating costs and a high adjusted tax rate.

Return on average capital employed calculated on an adjusted basis was 37.5% in 2006, higher than in 2005 (32.4%).

Oil and natural gas production for the year averaged 1.77 mmboe/d, up 1.9% from 2005. This included the loss of production at the Venezuelan Dación oilfield and lower entitlements in certain Production Sharing Agreements (PSAs) and buy-back contracts due to higher oil and gas prices. Eni delivered its 3% production growth rate based on a $55 per barrel scenario, as announced in the 2006 quarterly production outlook.
  Net proved reserves at December 31, 2006 stood at 6.44 bboe (down 6% from December 31, 2005), representing 10 years of remaining production at the current rate. Organic proved additions, as calculated by applying a year-end Brent price of $58.925 per barrel, replaced 65% of production. Assuming Brent is constant at $40 per barrel when determining entitlements in PSAs, the three-year average proved reserve replacement ratio would be 106%.

Eni invested euro 3.6 billion in the development of oil and natural gas reserves, in particular in Kazakhstan, Angola, Egypt and Italy. In exploration activities Eni invested euro 1.4 billion (up 106% compared with 2005) to support reserve replacement and the renewal of its portfolio.

In 2006, Eni achieved several hydrocarbon discoveries, mainly in Indonesia, Egypt, Kazakhstan, Norway, Nigeria, the United Kingdom, the Gulf of Mexico, Italy, Angola and Congo. A total of 68 exploratory wells were completed (35.9 net to Eni), with a commercial rate of success of 43% (49% net to Eni). A further 26 wells were in progress as of the year-end.

Eni’s exploration portfolio was strengthened through acquisition of assets in both core areas such as Angola, Alaska, Brazil, Congo, Egypt, Nigeria, Norway, Pakistan, the Gulf of Mexico and new countries/areas with high mineral potential such as Mali, Mozambique and East Timor. Gross acquired acreage extends for approximately 259,000 square kilometers (152,000 net to Eni, 99% operated).

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ENI FACT BOOK / EXPLORATION & PRODUCTION - STRATEGIES

MAINTAIN STRONG PRODUCTION GROWTH
Eni’s strategy is to build on its strong position in some of the world’s most attractive oil and gas basins to deliver industry leading production growth. We plan to accomplish this by applying the most cost-effective technologies and operations management systems to each and every asset to maximize the commercial recovery of hydrocarbons.
Eni’s assets are well balanced between mature producing fields and fields that are at the early stages of their producing cycles with significant opportunities for growth. Mature areas include mainland and offshore Italy, the North Sea and certain basins in Egypt. Growing areas include Libya, offshore and onshore West Africa, the Caspian Sea and the Nile Delta. Eni expects contributions from the latter to boost production growth to 2010 and beyond.
Eni continually invests in its existing asset base to increase resource recovery, maximize profitability, and extend field life. New production volumes are generated through workovers, drilling of new wells, and project implementation. In 2006, Eni invested euro 3.6 billion to develop new reserves and to maximize resource recovery from existing fields. In the next four years, Eni plans to invest approximately euro 322.5 billion evenly allocated to initiatives intended to counteract mature field decline, fuel medium-term growth and support growth beyond 2010.
Several fields/projects were started up during 2006. Among the key start-ups are: (i) the Benguela/Belize and Lobito/Tomboco fields in Block 14 (Eni’s interest 20%) in Angola, holding recoverable reserves of approximately 460 mmbbl. Peak production at 158 kbbl/d (20 net to Eni) is expected in 2009 upon completion of the drilling program; (ii) the fifth train as a part of the development of the Bonny liquefaction plant (Eni’s interest 10.4%) in Nigeria, increasing plant capacity to 17 mmtonnes/y of LNG (812 bcf/y of feed gas); (iii) the gas phase of the Bayu-Undan field (Eni’s interest 12.04%) in Australia, starting supplies to the Darwin plant with liquefaction capacity of 3.5 mmtonnes/y of LNG. Peak production at 160 kboe/d (18 net to Eni) is expected in 2008.


Production volumes outlook
In 2006, oil and gas production averaged 1,770 kboe/d, up 33 kboe from 2005 or 1.9%, despite: (i) the impact of the loss of production at the Dación oil field in Venezuela (down 46 kboe/d) as a consequence of the unilateral cancellation of the relevant service contract by the Venezuelan state oil company PDVSA; and (ii) adverse entitlement effects (down 21 kboe/d) in PSAs and buyback
  contracts due to higher oil prices. Production growth was driven by a remarkable increase in gas production mainly in Libya, Egypt, Nigeria, Australia and Croatia; oil production increased in Angola and Libya. Organic growth was partially offset by mature field declines and production outages in Nigeria due to social unrest. The share of production outside Italy was 87% (85% in 2005).
In the medium term, Eni expects to deliver a 3% compound average growth rate from 2007 to 2010, targeting a production level in excess of 2 mmboe/d by 2010. In subsequent years and up to 2013, Eni projects an annual growth rate of 3%. This goal will be achieved entirely through organic growth mainly in our key producing basins of North and West Africa and the Caspian region, leveraging on Eni’s unique position and solid relationships with many of the fastest growing producing countries in the world and on its strong pipeline of capital projects and investment opportunities. In greater detail, production growth will be fed by means of:
  • developing LNG projects, aiming at monetizing our large gas reserve base;
  • starting up new fields, some of which already under execution and other waiting for finalization of exploratory and appraisal activities;
  • leveraging on our long life fields, including Karachaganak in Kazakhstan, the Western Libyan Gas project, Val d’Agri in Italy, Ekofisk and Aasgard offshore Norway, Belayim and Port Fouad in Egypt, and, in perspective, our massive Kashagan field;
  • optimizing reserve recovery from declining fields.

Eni’s future production profiles are based on a long-term Brent price assumption of 40 $/bbl in real terms.

ENSURE MEDIUM TO LONG-TERM BUSINESS SUSTAINABILITY BY FOCUSING ON RESERVE REPLACEMENT

Eni intends to pay special attention to reserve replacement in order to ensure the medium to long term sustainability of its business. In pursuing this goal, Eni intends to:

  • optimize its portfolio of development properties by focusing on core areas, seeking new opportunities and divesting marginal assets;
  • pursue new exploration opportunities targeting a sound balance between high risk/high reward initiatives and established/mature projects.

As of December 31, 2006, Eni’s portfolio of mineral rights consisted of 1,029 exclusive or shared rights for exploration and development in 36 countries on five continents for a total net acreage of 385,219 square kilometers. Of these, 48,273 square kilometers concerned production and development.

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This geographically and geologically diverse, high-quality portfolio balances risks and rewards to deliver both near-term and long-term production growth. In the medium term, Eni expects to more than replace produced reserves through organic additions. Eni’s reserve replacement ratio will be supported by the high mineral potential of our assets located in core areas such as the Caspian Sea, West and North Africa.
The success of Eni’s approach is demonstrated by its ability in replacing produced reserves. In the 2003-2006 four-year period, exploration reserves discovered were approximately 700 mmboe on average for a cumulative amount of 2.8 bboe, higher than our cumulative production over the same period frame. Positive contributions came from both legacy countries such as Nigeria, Angola, Egypt and Kazakhstan and new frontier areas such as the Barents Sea and the ultra-deep waters of the Gulf of Mexico. At 25 bboe, our solid resource base1 will secure 38 years of production at current rates.
Under SEC reporting standards, proved reserves at 2006 year-end were 6.4 billion boe, representing a life index of 10 years. In the 2004-2006 period, considering adverse entitlement impacts in certain PSAs and buy-back contracts resulting from higher oil prices and assuming Brent constant at $40 per barrel when determining entitlements in PSAs, we would have replaced on average 106% of production through organic additions. For 2006 only, by applying the year-end price of $58.925/bbl, organic additions for the year came in at 417 mmboe with a reserve replacement ratio of 65%.
Exploration activities will play a crucial role in enlarging Eni’s resource base in order to fuel new production, and in securing access to new opportunities. In light of this, management will devote a great deal of focus and effort to exploration. In 2006, Eni more than doubled its investment in exploration from the previous year, resulting in a total of 68 wells drilled with an SEC exploration success of 43%, and capturing 12 new opportunities spanning from new, untested exploration plays to well established plays or already-discovered resources, for a total acreage of about 152,000 square kilometers net to Eni, of these 99% as operator. In the next four years, management plans to invest on average approximately euro 31.1 billion per year in exploration activities, resulting in a cumulative euro 34.4 billion that is substantially higher (+51%) than the previous four-year
  plan (2006-2009). The cornerstones of Eni’s exploration strategy are:
  • selectively assess opportunities to enhance the competitiveness of Eni’s full-cycle production costs;
  • concentrate resources in core areas: approximately 70% of planned investment will be directed to 10 countries;
  • exploit the full mineral potential of recently acquired areas;
  • complete portfolio renewal.

In fact, management intends to concentrate investments in well established areas of presence where availability of production facilities, existing competencies and log-term relationships with host countries will enable Eni to readily put in production discovered resources, reducing the time to market and capturing synergies. On the other hand, Eni expects to selectively pursue high risk/high reward opportunities arising from expansion in areas with high mineral potential. Finally, portfolio renewal will be completed, bearing in mind that approximately 70% of total acreage has been renewed over the last three years.


DEVELOP IN LNG BUSINESS
Eni operates its gas business as an integrated portfolio in order to fully extract value from the gas chain and to monetize its large gas reserves. Liquefied Natural Gas is a key part of this strategy. Eni intends to build a global LNG business, aiming at:

  • exploiting gas equity availability in order to supply the attractive markets of Europe and North America;
  • growing LNG production in areas with high potential and low producing costs;
  • purchasing interests in liquefaction plants in order to support the development of the LNG business.

Net liquefaction capacity in 2006 was 321 bcf, mainly concentrated in Nigeria and Egypt, and is expected to expand to 343 bcf in 2010 and in excess of 509 bcf in 2012 by means of developing capacity at the Bonny liquefaction plant, building the new Brass plant in Nigeria, and implementing the expansion plan of the Damietta LNG plant in Egypt.LNG sales are expected to grow from127 bcf in 2006 to166 bcf in 2010; equity gas supplies to LNG plants of 162 bcf in 2006 are expected to increase up to 233 bcf in 2010.

 

     
(1)   Oil and gas volumes contained in a reservoir as ascertained based on available engineering and geological data (sum of proved, probable and possible reserves) plus volumes not yet discovered but that are expected to be eventually recovered from the reservoir net of a risk factor (risked exploration resources).

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ENI FACT BOOK / EXPLORATION & PRODUCTION - ACTIVITY AREAS

ACTIVITY AREAS

Italy
Eni has been operating in Italy since 1926. In 2006 Eni’s oil and gas production amounted to 238 kboe/d. Eni’s activities in Italy are deployed in the Adriatic Sea, the Central Southern Apennines, mainland and offshore Sicily and the Po Valley on a total acreage of 28,508 square kilometers (22,496 net to Eni). Eni’s exploration and development activities in Italy are regulated by concession contracts.

Production is expected to remain stable in the medium term despite mature field declines, owing to the continued ramp up of production in Val d’Agri, development projects underway and initiatives for supporting production levels in gas fields.

Sicily
Production Eni is operator of 13 production concessions onshore and offshore Sicily. Its main fields are Gela, Ragusa, Giaurone, Fiumetto and Prezioso, which in 2006 accounted for 6% of Eni’s production in Italy. In the second half of 2006, the Samperi well was started up with full production of approximately 2,871 cf/d to be reached in 2007.
Development The main development projects underway concern gas onshore Sicily: (i) Pizzo Tamburino, the project provides for the drilling of two producing wells, the installation of facilities for liquids/gas separation and the linkage to the Gagliano station by means of a 16-kilometer long pipe. The start-up of the first well, Pizzo Tamburino, is scheduled for the second half of 2007
 

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with expected production of approximately 5.74 mmcf/d; (ii) the recovery of additional reserves in the Fiumetto concession by means of the drilling of the Fiumetto 1 well expected to start-up in the first half of 2007 with an expected production increase of approximately 3,445 cf/d.
Exploration Exploration activity yielded positive results with gas discoveries in the GR.13.AG offshore permit (Eni’s interest 60%) with the Argo 1 well, which yielded up to 769 cf/d in test production. In the San Teodoro onshore permit, mineral surveys are underway on the Borgo Giuliano 1 well. A concession has been requested after this discovery
 

Adriatic Sea
Production The Adriatic Sea represents Eni’s main production area in Italy, accounting for 49% of Eni’s domestic production in 2006. Main operated fields are Barbara (177 mmcf/d net to Eni), Angela-Angelina (71 mmcf/d), Porto Garibaldi (71 mmcf/d) and Cervia (57 mmcf/d). Activities for the year concerned mainly the optimization of the Barbara, Daria, Basil and Anemone gas fields by means of sidetrack and infilling action aimed at supporting production levels and the Rospo oil field with the drilling of two new wells.
Development The main project underway concerns the development of gas reserves in the Tea-Arnica-Lavanda

field. The project provides for the installation of a production platform and the linkage of 4 wells to the existing nearby facilities. Production volumes will be delivered to the Ravenna Mare station. Production start-up is scheduled for 2007 with an expected production peak of approximately 35 mmcf/d to be reached in the same year.
Exploration Exploration activity yielded positive results with a gas discovery in the AR.95.EA permit with the Benedetta 1 well, which yielded up to 5,121 cf/d in test production.

Po Valley
Exploration Exploration activity yielded positive results with a gas discovery in the San Potito concession with the drilling of the Longanesi 1 well, which yielded 3,143 cf/d in test production.
  Central-Southern Apennines
Production Eni is operator of the Val d’Agri concession (Eni’s interest 60.77%) in Basilicata, resulting from the unitization of the Volturino and Grumento Nova concessions made in late 2005. Recoverable reserves in this concession amount to 608 mmboe. Production from the Monte Alpi, Enoc and Cerro Falcone fields is fed by 22 production wells of the 27 foreseen by the sanctioned development plan and is supported by the Viggiano oil center, containing 6 trains with a treatment capacity of 104 kbbl/ day of oil and 99 mmcf/d of natural gas.
Oil produced is carried to Eni’s refinery in Taranto via a 136-kilometer long pipeline. In 2006 the Val d’Agri concession produced 105 kboe/d (68 net to Eni) corresponding to 29% of Eni’s production in Italy.

 

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Development The main project underway concerns the development of the oil and gas onshore Miglianico field (Eni’s interest 100%). The project provides for the linkage of 3 wells, the construction of a treatment facility for oil, which will be supplied to Eni’s Refining & Marketing logistic facilities, while the gas will be input to the national transport network through a pipeline. Production start-up is scheduled for the second half of 2008 with an expected production peak of 7.2 kboe/d to be reached in 2009. As for the development of gas reserves, the project in the South-West area of the Candela permit is well underway, with production start-up expected in the second half of 2007.
Activities in the Val d’Agri concession concerned the continuation of the drilling program and the upgrading of production facilities.
Exploration Exploration activity yielded positive results with a gas discovery in the Mezzocolle concession with the drilling of the Longanesi 1 well.

  North Africa

Algeria
Eni has been present in Algeria since 1981. In 2006, Eni’s oil production averaged 91 kboe/d. Operating activities accounting for 53% of Eni’s production in Algeria are located in the Bir Rebaa area in the South-Eastern desert and include the following exploration and production blocks: a) Blocks 403 a/d (Eni’s interest 100%); b) Blocks 401a/402a (Eni’s interest 55%); c) Block 403 (Eni’s interest 50%); d) Blocks 212 (Eni’s interest 22.38%) and 208 (Eni’s interest 12.25%); e) exploration Blocks 404a (Eni’s interest 25%) and 403 c/e (Eni’s interest 33.33%). Gross acreage of Eni’s interests in Algeria was 12,739 square kilometers (3,456 net to Eni). Exploration and production activities in Algeria are regulated by Production Sharing Agreements (PSA) and concession contracts.
In the medium-term, Eni expects production in Algeria to increase reflecting ongoing development activities, targeting a 100 kboe/d level by 2010.


BLOCKS 403 a/d
Production Production in the area is supplied mainly by the HBN and Rom and satellite fields. Blocks 403 a/d accounted for approximately 46% of Eni’s production in Algeria in 2006.
Development The main project underway is Rom/Zea Integrated Development for the production of reserves identified by the recent appraisal activity conducted in the area, leading to a revaluation of the resources of this area. Current production is collected at Rom’s Central Production Facility and delivered to the treatment centre in Bir Rebaa North in Block 403. The project provides for the upgrade of production facilities and the injection into the field of water and gas currently flared at the Rom satellite center. As a result, flared gas is expected to be reduced by approximately 90%, as required by applicable Algerian laws. Production is expected to peak at 21 kbbl/d (12 net to Eni) in 2010.
Exploration Exploration activity yielded positive results with the finalization of an appraisal campaign intended to evaluate reserves in the area covered by the Rom Integrated project as described above.

BLOCKS 401a/402a
Daily production from the area is supplied mainly by the Rod and satellite fields. Blocks 401a/402a accounted for approximately 27% of Eni’s production in Algeria in 2006. Infilling activities are being performed on producing fields in order to maintain the current production

 

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plateau. The drilling of further 6 wells (4 production and 2 water injection wells) is planned for the recovery of recently ascertained reserves.

BLOCK 403
The main fields in the area are BRN, BRW and BRSW. Block 403 accounted for approximately 13% of Eni’s production in Algeria in 2006. Exploration activity remains intense in this area.

BLOCK 208
Block 208 is located south of Bir Rebaa. The El Merk Synergy plan for the development of this block in conjunction with the development of adjoining blocks (212 and 405a and 404 operated by other companies) is the main project underway in Algeria and is aimed at producing recoverable reserves up to 728 mmboe.
In Block 208 the EKT, EMK, EMN and EME oil and gas fields, discovered between 1993 and 1998 are expected to be developed. The working plan provides for the drilling of 145 wells, that will be linked to a Central Production Facility with a treatment capacity of 150 kbbl/d of oil and approximately 1 bcf/d of associated wet gas for the extraction of liquids (approximately 50 kbbl/d) and the subsequent gas cycling (reinjection in the field). Marketing of associated gas is envisaged 8 years after the production is started up. Start up is expected in 2010 peaking at

144 kboe/d (19 net to Eni) in the same year. About 85% of basic engineering has been completed in 2006.

BLOCK 404a
This block is only in the exploration phase. In 2006 the BBKS-1 discovery well showed the presence of oil and yielded approximately 700 kbbl/d in test production.
The BBKSE-1 appraisal well showed the presence of oil at a depth of about 3,200 meters and confirmed the eastward extension of the BBKS structure.

  Egypt
Eni has been present in Egypt since 1954 and is the first international operator in oil and gas with a gross production amounting to 523 kboe (227 kboe net to Eni) in 2006, on a total acreage of 23,214 square kilometers (13,901 net to Eni).
Eni’s main producing activities are located in the Belayim concession (Eni’s interest 100%) located in the Gulf of Suez which contains oil and condensates and in the North Port Said (former Port Fouad, Eni’s interest 100%), Baltim (Eni operator with a 50% interest), Ras el Barr (Eni’s interest 50%) and el Temsah (Eni operator with a 50% interest) predominantly gas concessions located offshore in the Nile Delta. In 2006 production from these concessions accounted for 90% of Eni’s production in Egypt.
Exploration and production activities in Egypt are regulated by concession contracts and PSAs.
Production is expected to increase in the medium term reflecting ongoing development of gas reserves, despite expected production decline of mature oil fields. Eni targets a production level of 250 kboe/d in 2010, making Egypt Eni’s first hydrocarbon producing country by that date.

GULF OF SUEZ
Production Oil and condensate production came mainly from the Belayim field, Eni’s first large discovery of oil in Egypt, which produced 51 kbbl/d net to Eni in 2006.
Other producing assets are located in the Ashrafi concession, which in 2006 produced 6 kbbl/d.
Exploration Exploration activity aims at the recovery of the residual mineral potential of this area in order to contain the natural decline of producing fields. In 2006 the Abu Rudeis Marine 4 discovery was made and showed the presence of oil at a depth of over 3,000 meters; the well has been linked to existing production facilities.

NILE DELTA

NORTH PORT SAID
Production In this concession Eni’s production in 2006 amounted to 459 mmcf/d net to Eni, also following the reaching of full production of the Barboni field started up in 2005. In 2006 the Anshuga gas field was started up and linked by sealines to the production facilities of the nearby Nouras field. Production is targeted at approximately 18 mmcf/d net to Eni.
Part of the production of this concession is destined to the NGL (natural gas liquids) plant owned by United Gas Derivatives Co (Eni’s interest 33%) with a treatment capacity of 1,095 mmcf/d of natural gas and a yearly production of 330 ktonnes of propane, 280 ktonnes of LPG and 1.1 mmbbl of condensates.

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Development Ongoing development activities aim at supporting the current gas production level of 459 mmcf/d net to Eni. The Semmani field is under development by means of the drilling of 2 producing wells to be linked by sealines to the nearby production platforms. Start-up is expected in 2007 with a flow of approximately 1 mmcm/d net to Eni. Upgrading activities of the el Gamil terminal have been progressing. This project provides for the expansion of a compression station and the installation of a new unit linked to the el Temsah and Ras el Barr producing areas.

BALTIM
Production In this concession Eni’s production in 2006 amounted to 106 mmcf/d net to Eni.

  RAS EL BARR
Production This concession contains three fields: Ha’py, Akhen and Taurt and is located about 25 kilometers north-west of el Temsah. Eni’s production in 2006 amounted to 177 mmcf/d.
Development Ongoing development activities aim at supporting the current gas production level of 170 mmcf/d net to Eni. In 2006 the first phase of the installation of gas compression units along the sealine linking to the West Harbour terminal for the development of the Ha’py field was completed.
Engineering activities are underway for the development of recoverable gas reserves amounting to 932 bcf of the offshore Taurt field. This project provides for the drilling of 7 production wells which are expected to be linked to existing onshore treatment facilities. Production is expected to start in 2008.

EL TEMSAH
Production Eni’s production in 2006 amounted to 64 mmcf/d due to the start-up of the Temsah NW 2 production platform.
Development Ongoing development activities aim at reaching a gas production peak of 111 kboe/d (33 net to Eni) in 2008. Engineering activities are underway for the development of the gas reserves in the Denise field. The project provides for two phases.
The first one entails the drilling of 4 producing wells to be linked to the Denise A facility installed on the Temsah NW 2 platform. In the second phase, 4 more production wells will be drilled and the Denise B platform is to be installed and linked to the Temsah NW 2 platform. Production start-up is expected in 2008.

EXPLORATION IN THE NILE DELTA AREA
An intense exploration campaign is underway for ascertaining the large mineral potential of the Nile Delta area. In 2006 exploration yielded positive results with the NFW Meret 1 and 2 wells which showed the presence of layers containing gas and condensates in the western area of the el Temsah concession at a depth of over 1,500 and 3,000 meters, respectively.
In the Thekah permit the Thekah North discovery well (gas) is waiting to be linked to existing production facilities.

WESTERN DESERT
Other production activities are located in the Western Desert, in particular in the Melehis (Eni’s interest 56%) and West Razzak (Eni’s interest 80%) concessions containing mainly oil. Concessions in the Western

 

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Desert accounted for approximately 7% of Eni’s production in Egypt in 2006.
Exploration activity yielded positive results with the Aghar SW-1X oil discovery in the West Razzak concession, the Lotus North 1-X and Nada Ne 1-X oil wells in the Melehis concession. The latter two wells have started production.

THE LNG BUSINESS IN EGYPT
Eni owns a 40% interest in the Damietta natural gas liquefaction plant. As part of the expansion plan of the plant, Eni and its partners signed a framework agreement in June 2006 for doubling the capacity of the plant by means of the construction of a second train with a treatment capacity of 5 mmtonnes/y of LNG corresponding to approximately 268 bcf/y of gas for a twenty-year period starting in 2010. Eni will supply 88 bcf/y to the second train from new gas discoveries in the Nile Delta, some of which in the deep waters. A new company is going to be established for the construction of the plant made up of Eni, Unión Fenosa, SEGAS (Spanish Egyptian Gas Co), BP and Egyptian national companies EGAS and EGPC. Eni already supplies approximately 53 bcf/y to the first train of the plant for a twenty year period.

Libya
Eni started operations in Libya in 1959. In 2006 Eni’s oil and gas production averaged 222 kboe/d, the portion of liquids being 65%. Production activity is carried out in the Mediterranean offshore facing Tripoli and in the Libyan desert area, over a total acreage of approximately 39,569 square kilometers (34,113 net to Eni).
The main production blocks in which Eni holds interests are: (i) onshore NC169A (Eni’s interest 50%) and offshore NC41 (Eni’s interest 30% for oil and 50% for gas); (ii) onshore NC 174 (Eni’s interest 33.3%) and (iii) onshore concessions 82 and 100 (Eni’s interest 50%).
Eni also holds a 50% interest in the NC118 block where, after a declaration of commercial discovery, it is developing the A-NC118 field.
In the exploration phase, Eni is operator of four onshore blocks in the Muzurk basin (161/1, 161/2&4, 176/3) an in the Kufra area (186/1, 2, 3 & 4).
Exploration and production activities in Libya are regulated by concessions and PSAs.
Eni’ s production in Libya is expected to post an increase in the medium term owing to
  the expected ramp up of new structures near the Western Libyan Gas Project fields, despite mature field production declines. Libya confirms to be one of Eni’s largest oil and gas producing countries

BLOCKS NC169/NC41
Production Block NC169 is located in the western Libyan desert near the border with Algeria while block NC-41 is located in the Mediterranean offshore north of Tripoli. Production comes from: (i) the onshore Wafa field started up in September 2004, which in 2006 produced 139 kboe/d of liquids and natural gas (69 net to Eni); (ii) the Bahr Essalam offshore field started up in August 2005, that in 2006 produced 102 kboe/d of liquids and natural gas (51 net to Eni); (iii) the Bouri offshore field (Eni’s interest 30%) discovered in 1976, that in 2006 produced 55 kboe/d of liquids (17 net to Eni).
The Wafa and Bahr Essalam fields, containing recoverable reserves of approximately 1.6 bboe were developed as part of the upstream-midstream integrated Western Libyan Gas Project aimed also at exporting natural gas to Europe through the underwater Greenstream pipeline. In 2006 volumes delivered through this pipeline were 240 bcf and are expected to target 283 bcf (equal to approximately to an average of 777 mmcf/d) when operations are fully on line. Said volumes are supplied to third parties on the Italian natural gas market under long term contracts. Further 71 bcf of gas will be delivered to the Libyan market once these two fields have achieved production plateau. Production from these two fields is treated at the Mellitah plant on the Libyan coast, made up of three trains for the treatment of gas from Bahr Essalam, while the gas produced at Wafa is ready for sale. Mellitah includes also facilities for the compression of natural gas that is carried to Sicily, as well as facilities for the storage and loading of oil and LPG. In 2006 a total of 26 offshore producing wells were drilled and linked to the Sabratha platform as foreseen by phase 1 of the sanctioned project.
The Bouri field is exploited through two platforms linked to an FPSO unit with a storage capacity of approximately 1.5 mmbbl. In 2006 the Bouri East Development project was completed with the start-up of 4 underwater wells.

Exploration Exploration activity was successful with the T1 discovery well, about 20 kilometers west of the Bouri field, which identified oil at a depth of 2,800 meters.

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BLOCK NC174
Production Block NC174 is located in the south-western Libyan desert about 800 kilometers from of Tripoli. Daily production is provided mainly by the El Feel (Elephant) field discovered in 1997. In 2006 the field yielded 124 kbbl/d (24 net to Eni) treated at the field’s facilities and then delivered to the Mellitah treatment plant by pipeline.
After completing the storage and loading facilities of the Mellitah terminal, this field reached a production peak of 150 kbbl/d (35 net to Eni).

BLOCKS 82 AND 100
Production These blocks are located in the eastern-central Libyan desert. Oil production is provided by the Bu Attifel oil field discovered in 1967 and started-up in 1972, as well as by minor fields in concession 82. In 2006 they yielded 106 kbbl/d (53 net to Eni). Development activities concerned the drilling of some infilling wells.

  Exploration Exploration activity was successful with the KK4-82/ST3 discovery well, which identified oil at a depth of approximately 5,000 meters.

Mali
In November 2006, Eni purchased five onshore exploration licenses (Eni operator with a 50% interest) from the companies Baraka Mali Operations Limited and Baraka Mali Ventures Limited, covering a gross acreage of approximately 193,200 square kilometers (96,600 net to Eni). Blocks are located in the central part of the Taodueni Basin at the border with Algeria, a completely unexplored and high potential basin according to recent studies. The life span of this exploration license was fixed at four years. In March 2007, this operation was approved by the Malian Authorities.

West Africa

Angola
Eni has been present in Angola since 1980. In 2006 Eni’s oil production averaged 155 kboe/d. Eni’s activities are concentrated in the conventional and deep offshore over a gross acreage of 18,776 square kilometers
(3,275 net to Eni).
The main blocks in which Eni holds an interest are: (i) Block 0 in Cabinda (Eni’s interest 9.8%) west of the Angolan coast; (ii) Block 14 (Eni’s interest 20%) in the deep offshore west of Block 0; (iii) Block 15 (Eni’s interest 20%) in the deep offshore of the Congo basin.
Eni also holds interests in other minor concessions,
in particular in some areas of Block 3 (with interests varying from 12 to 15%).
In the exploration phase, Eni is operator of block 15/06 (with a 35% interest) awarded in May 2006 and holds interests in the 14K/A IMI Unit Area and in Block 3/05-A with a 11.5% and a 12% interest, respectively.
Exploration and production activities in Angola are regulated by concessions and PSAs.
Production is expected to increase in the medium term reflecting contributions from ongoing development projects, despite the production decline of mature fields. By 2010 Angola will confirm its status as one of Eni’s largest oil and gas producing countries with a level of 160 kbbl/d.

BLOCK 0
Production In 2006 production from this block accounted for approximately 27% of Eni’s production in Angola at 41 kbbl/d (gross production averaged 418 kbbl/d). Block 0 is divided into areas A and B Oil production from area A, deriving mainly from the Takula

 

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and Malongo fields amounted to 22 kbbl/d net to Eni. Production of area B including oil, condensates and LPG derives mainly from the Bomboco, Kokongo, Lomba, N’Dola, Nemba and Sanha fields, and amounted to 19 kbbl/d net to Eni in 2006. In 2007 Eni’s production from Block 0 is targeted at 40 kbbl/d.
Development The development plan of the Banzala field in area A progressed towards completion, with the commissioning of the first of the two production platforms envisaged by the plan and the drilling of development wells. Production start-up is expected in the first half of 2007, peaking at 27 kbbl/d (3 net to Eni) in 2009.

BLOCK 14
Production Block 14 produced 108 kbbl/d (17 net to Eni) in 2006 and is one of the most fruitful areas in the West African offshore, recording 9 commercial discoveries to date. In 2006 the joint development of the Benguela-Belize/Lobito-Tomboco oil fields has been completed. Phase 1 has been started up in January, while phase 2 was started up in June. Production from these fields holding recoverable reserves of 380 mmbbl is supported by a Compliant Piled Tower provided with treatment facilities for Benguela/Belize and an underwater linkage system for Lobito/Tomboco. Peak production of 158 kbbl/d (20 net to Eni) is expected in 2009 with the finalization of the drilling program.
Development Eni participates to the development project of the Landana and Tombua deepwater oil fields discovered in 1997 and 2001 respectively, holding recoverable reserves of 322 mmbbl in water depths between 270 and 500 meters. The development project includes the drilling of 46 subsea wells, 6 of which related to the Landana North field, that are expected to be linked to the Benguela/Belize-Lobito/Tomboco facilities. The first of these wells started producing in June 2006. The remaining part of the project will be carried out by means of the installation of a Compliant Piled Tower provided with treatment capacity. Production is planned to start up in 2009 peaking at 130 kbbl/d (22 net to Eni) in 2011 once the drilling program has been completed. Associated gas will be reinjected in the reservoir.
Exploration Exploration activity was successful with the Lucapa 1 discovery, which identified oil and gas at a depth of approximately 1,200 meters.

BLOCK 15
Production In 2006 production from this block averaged 573 kbbl/d (90 net to Eni). This is considered the most interesting area in the West African offshore with recoverable reserves estimated at 2.55 bbbl of oil.
 

The Hungo and Chocalho fields were started up in August 2004, and the Kissanje and Dikanza fields were started-up in July 2005 as part of phases A and B of the global development plan of the Kizomba reserves. Production from these fields is supported by FPSO units. In 2006, these fields yielded a cumulative production of 527 kbbl/d (85 net to Eni), nearing peak levels. In the medium-term,

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peak production is expected to be supported by developing reserves from nearby discoveries. In December 2006 the Marimba oil field, discovered in 1998, was started up. The project provides for the drilling of 5 wells (3 production and 2 water injection wells) that will be linked to the existing production facilities.
Production from this satellite is expected to peak at 39 kbbl/d (7 net to Eni) in 2008.
Another large field in Block 15 is Xikomba, yielding 4 kbbl/d net to Eni in 2006.
In 2006 production from Block 15 accounted for approximately 59% of Eni’s production in Angola.
Development In March 2006 the development of the Mondo and Saxi/Batuque fields was sanctioned as part of phase C of the global development plan of the Kizomba reserves. The Mondo field contains recoverable reserves of 278 mmbbl. The relevant development project provides for the installation of an FPSO vessel with a treatment capacity of 100 kbbl/d and a storage capacity of approximately 2 mmbbl and the drilling of 17 wells (10 producing, 4 water injection and 3 water/gas injection wells). The Saxi/Batuque fields holding recoverable reserves of 305 mmbbl will be developed according to a scheme similar to that of the Mondo field by installing an FPSO vessel with a treatment capacity of 100 kbbl/d and a storage capacity of approximately 1.7 mmbbl, and drilling 19 wells (9 producing, 6 water injection and 4 water/gas injection).
Production is expected to start in the first and second quarter of 2008, respectively, peaking at 100 kbbl/d for both projects (18 net to Eni) in 2009.
.

Exploration Exploration activity was successful with the Tchihumba 2 discovery, which identified oil and gas at a depth of approximately 3,000 meters.

BLOCK 3/05-A
In March 2006 a joint operating agreement was signed for Block 3/05-A (Eni’s interest 12%).
The exploration program provides for the drilling of an exploration well in three years and the option for an extension of the agreement for further two years and the drilling of another well.

 

BLOCK 14K/A IMI Uni
In this block the Lianzi discovery was made and further appraisal activity confirmed the presence of natural gas and oil and gas layers at a depth of more than 3,000 meters. In January 2006 the area was qualified for development and the partners of the project are quantifying the recoverable reserves it contains for the definition of production plans.

BLOCK 15/06
In May 2006, following an international bid procedure Eni acquired a 35% interest in an exploration license in offshore Block 15/06 acting as operator. This area is believed to hold a high mineral potential.
Total acreage extends for approximately 3,000 square kilometers located 350 kilometers off the coast in the Lower Congo Basin at a water depth between 200 and 1,500 meters. The exploration plan provides for the acquisition of 1,500 square kilometers of seismic surveys, the drilling of 8 wells in five years and the option for a three year extension of the license with the drilling of 3 further wells. In November 2006, Eni signed the relevant production sharing contract with the Angolan national company Sonangol.

Congo
Eni has been present in Congo since 1968 and its activities are concentrated in the conventional and deep offshore facing Pointe Noire covering a gross acreage of 9,797 square kilometers (4,169 net to Eni). In 2006 production averaged 67 kboe/d net to Eni, mainly oil. Exploration and production activities in Congo are regulated by PSA.
Eni’s principal oil producing interests operated in Congo are the Zatchi (Eni’s interest 65%) and Loango (Eni’s interest 50%) fields and Blocks Marine VI (Eni’s interest 65%) and VII (Eni’s interest 35.75%).
Eni holds a 35% interest in the Pointe Noire Grand Fonde and Pex permits.
Eni also holds interests in the four deep offshore blocks Mer Très Profonde Nord (Eni operator with a 40% interest), Mer Très Profonde Sud (Eni’s interest 30%) and Marine X (Eni operator with a 72% interest).
In May 2006 Eni signed a Protocole d’Accord aimed at exploiting the gas mineral potential of the Marine XII permit for feeding a high yield power station.
In February 2007 Eni concluded an agreement with the Indian company ONGC Videsh whereby exploration interests in India and Congo were exchanged. Following this transaction Eni acquired a 34% interest in block MN-Dwn-2202/1 with high mineral potential in the Indian offshore at a water depth of 2,000 meters

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with a total acreage of 10,000 square kilometers and will give to its partner a 20% interest in the Mer Très Profonde Nord permit (Eni operator with a 40% interest) offshore Congo.
In February 2007, Eni acquired certain onshore exploration and production assets operated by Maurel & Prom. This transaction includes the producing fields of M’Boundi (48.6%) and Kouakouala A (66.7%), the production concession of Kouakouala B (50%) and interests in the Kouilou (50%) exploration permit.
The transaction is subject to approval of the relevant Congolese Authorities. To date the proved reserves contained in the assets purchased amount to 325 mmbbl (approximately 126 net to Eni). Production expected in 2007 is 43 kbbl/d and is expected to increase in the future due to water injection activities.
Production in Congo is expected to increase in the medium term due to the contribution from recently acquired assets, targeting a level of 100 kbbl/d.

  Production Daily production is provided mainly by the Zatchi (approximately 16 kbbl/d) and Loango (10 kbbl/d) fields, Tchibuela and Yanga/Snedji fields in the Pointe Noire Grand Fonde permit (overall 14 kbbl/d) and by fields located in the Marine VI (approximately 11 kbbl/d) and Marine VII (3 kbbl/d).
Eni holds a 50% interest in the Djeno power plant.
The plant has a 25 MW capacity and is fired with associated gas from the Kitina field (in Marine VII permit). It was started up in 2002 and represents the first example of monetization of associated gas in Congo.
In 2006 in the Pex permit the Litanzi offshore field started production through the facilities of the Tchendo field. A peak production of 4.1 kboe/d (1.4 net to Eni) was reached in 2006.
Development The main development project underway concerns the Awa Palokou (Eni’s interest 90%) and Ikalou-Ikalou Sud (Eni’s interest 100%) fields in the Marine X and Madingo permits. Start up is expected in 2008 with a production peak of 13 kboe/d net to Eni in 2009.
Exploration Exploration yielded positive results in the Mer Très Profonde Sud permit with the Aurige Nord Marine discovery that yielded approximately 5 kboe/d in test production.

Nigeria
Eni has been present in Nigeria since 1962. In 2006, Eni’s oil and gas production averaged 149 kboe/d over a gross acreage of 43,215 square kilometers (7,356 net to Eni) located mainly in the onshore and offshore of the Niger Delta. In the development /production phase Eni is operator of 4 onshore Oil Mining Leases (OML) 60, 61, 62 and 63 (Eni’s interest 20%) and offshore OML 125 (Eni’s interest 50.19%), OMLs 120-121 (Eni’s interest 40%) and OML 118 (Eni’s interest 12.5%). It also holds a service contract for the offshore OMLs 119 and 116. Through SPDC JV, the largest oil joint venture in the country, Eni also holds a 5% interest in 31 onshore blocks and a 12.86% interest in 5 conventional offshore blocks.
Eni holds a 5% interest in offshore OML 28 where the Kolo Creek appraisal well showed the presence of hydrocarbons in the reservoir of the Kolo Creek structure.
In the exploration phase Eni is operator of Oil Prospecting Leases (OPL) 244 (Eni’s interest 60%), OML 134 (former OPL 211 - Eni’s interest 50.19%) and onshore OML 135 (former OPL 219 - Eni’s interest 12.5%) and OPL 282 (Eni’s interest 90%) In OML 135 exploration activity yielded positive results with the Bolia 4 appraisal well which discovered oil at a depth of 3,600 meters and opened the way to further surveys of the field.

 

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The partners of OMLs 135 and 129 are also appraising the development of the Nnwa-Doro field and a possible marketing of the gas.
In March 2007 Eni acquired a 48% interest and the operatorship of activities in OPL 135. The exploration program provides for the exploration and development of new oil and gas reserves near existing networks and the Kwake/Okpai power station operated by Eni over a period of 25 years. Exploration and production activities in Nigeria are regulated by Production Sharing Contracts. Eni’s counterparties are state owned oil companies, while in service contracts Eni acts as contractor for state owned companies. Service contracts provide for the recovery of reimbursable costs born by the contractor through a share of production, while non reimbursable costs (mainly costs related to dry wells) are recovered through the contractor’s share of profits.OPLs typically last 10 years. When a discovery is made OPLs are transformed into OMLs with a 20 year duration.
Production is expected to increase in the medium term in particular for the exploiting of gas reserves that will enable Eni to reach approximately 200 kboe/d, confirming Nigeria among Eni’s largest producing countries.
 

OMLs 60, 61, 62 and 63
Blocks OML 60, 61, 62 and 63 accounted for 39% of Eni’s production in Nigeria in 2006. Liquid and gas production is supported by the LNG plant at Obiafu-Obrikom with a treatment capacity of approximately 706 mmcf/d and by the oil tanker terminal at Brass with a storage capacity of approximately 3 mmbbl. A large portion of the gas reserves of these four OMLs is destined to supply the Bonny liquefaction plant (see below). Another portion of gas production is employed in firing the combined cycle power plant at Kwale-Okpai with a 480 MW generation capacity which started operations in 2005. In 2006 supplies to this power station amounted 71 mmcf/d (approximately 12 kboe/d). This project is part of the Nigerian government and Eni’s plans for the reduction of carbon dioxide emissions in the atmosphere. In late 2006 this project was qualified as CDM (Clean Development Mechanism) by the United Nations as provided for by the Kyoto Protocol. The CDM at Opkai power station is the first approved in Nigeria. Exploration activities in these blocks remain intense.

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OML 125
OML 125 produced 12 kbbl/d of oil net to Eni in 2006. Production derived from the Abo field, under development and expected to reach a peak production of 20 kbbl/d (9 net to Eni) by 2009. Production is assisted by an FPSO unit with a 45 kbbl/d capacity and a 800 kbbl storage capacity.

OML 118
OML 118 produced 22 kbbl/d of oil net to Eni in 2006. Production derived from the Bonga oil field, on which an FPSO unit with a 225 kbbl/d capacity and a 2 mmbbl storage capacity is installed. Associated gas is carried to a collection platform on the EA field and from here is delivered to the Bonny liquefaction plant.
Exploration yielded positive results with the Bonga North 2 appraisal well which showed the presence of oil at a depth of 3,560 meters.

OML 119
Located about 55 kilometers off the Nigerian coast at a water depth of 65 meters, OML 119 produced 17 kbbl/d of oil net to Eni in 2006. Production derived from the Okono/Okpoho field through an FPSO unit with an 80 kbbl/d capacity and a 1 mmbbl storage capacity.

OMLS 120 AND 121
An exploration plan is underway aimed at appraising the reserves in the Oyo discovery for a subsequent development. In OML 120 the Oyo dir appraisal well found oil at a depth of 2,730 meters.

SDPC JOINT VENTURE (NASE)
The Forcados/Yokri oil and gas field with recoverable reserves of 320 mmboe is under development as part of the integrated associated gas gathering project aimed at supplying gas to the Bonny liquefaction plant. Offshore production facilities have been installed. Onshore activities concern the upgrading of the Yokri and North/South Bank flow stations and the construction of a gas compression plant with a 8.1 bcf/d capacity. 28 wells have been drilled and 122 started production. Completion is expected in 2008.

THE LNG BUSINESS IN NIGERIA
Eni holds a 10.4% interest in Nigeria LNG Ltd which manages the liquefaction plant located on Bonny island, in the eastern part of the Niger Delta, with a treatment capacity of approximately 812 bcf/y of feed gas corresponding to a production of 17 million tonnes/year of LNG on 5 trains. A sixth train is under construction with a treatment capacity of 4.1
 

mmtonnes/y expected to start operations in 2007. Engineering activities of a seventh train are underway with expected start up in 2011. When fully operational, this plant is expected to have a capacity of 30 mmtonnes/y of LNG corresponding to about 1,448 bcf/y of feed gas.
Natural gas supplies to the plant (first six trains) will be provided under a gas supply agreement with a 20 year term from production of the SPDC joint venture and of OMLs 60, 61, 62 and 63. When fully operational in 2008, supplies will total approximately 3,461 mmcf/d (268 net to Eni, corresponding to approximately 46 kboe).
LNG production is sold under long term contracts and exported by the Bonny Gas transport fleet, wholly-owned by Nigeria LNG Co. This fleet is composed of 18 tanker ships and will be upgraded with 5 new units for the transport of production from train 6.
Eni is operator with a 17% interest of the Brass project for the construction of a natural gas liquefaction plant to be built near the existing Brass terminal (Eni’s interest 20%) on the Nigerian coast about 100 kilometers West of Bonny. This plant is expected to start operating in 2011 with a treatment capacity of 10 mmtonnes/y of LNG corresponding to 1,695 mmcf/d (approximately 177 net to Eni) of feed gas on 2 trains. Supplies to this plant will derive from the collection of associated gas from nearby producing fields and from the development of gas fields in OMLs 61 and 62 onshore. By February 2006 all memoranda of understanding have been signed pertaining to the marketing of the whole LNG production capacity of the plant for a period of 20 years. Eni acquired 2 mmtonnes/y of LNG capacity.

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North Sea

Norway
Eni has been operating in Norway since 1964. Eni’s activities are performed in the Norwegian Sea, in the Norwegian section of the North Sea and in the Barents Sea over a gross acreage of 18,851 square kilometers (7,077 net to Eni). Eni’s production in Norway amounted to 140 kbbl/d in 2006.
Exploration and production activities in Norway are regulated by Production Licenses (PL). According to a production license, the holder is entitled to perform seismic surveys and drilling and production activities for a few years with possible extensions.
In the medium term, production is expected to decline slightly due to production decline in mature fields, to recover later when ongoing development activities start to support production levels.

NORWEGIAN SECTION OF THE NORTH SEA
Production Eni holds interests in 4 production Licenses in the Norwegian section of the North Sea covering a total acreage of 2,168 square kilometers. The main producing field is Ekofisk (Eni’s interest 12.39%) in PL018 containing mainly oil, which in 2006 produced 416 kboe/d (52 net to Eni) and accounted for 37% of Eni’s production in Norway. In 2006 initiatives were executed to support and optimize production, in particular two further stretches of pipes were laid that will start operations in 2007.
Exploration Eni holds interests ranging from 12 to 60% in 5 prospecting Licenses, one of them as operator.

NORWEGIAN SEA
Production Eni holds interests in 6 production areas in the Norwegian Sea covering a gross acreage of 1,027 square kilometers. The main producing fields are Aasgard (Eni’s interest 14.82%), Kristin (Eni’s interest 8.25%), Heidrun (Eni’s interest 5.12%), Mikkel (Eni’s interest 14.9%) and Norne (Eni’s interest 6.9%) which accounted for 63% of Eni’s production in Norway. In 2006 the drilling program of the Kristin field was completed, after this intervention production is expected to reach 218 kboe/d (18 net to Eni) in 2007.
Development The main structures in the development phase are located near Kristin, in particular Tyrihans (Eni’s interest 6.23%). The development of this field is economically viable thanks to the synergies obtainable from the Kristin production facilities. The development plan of Tyrihans provides for the drilling of 12 wells (9 production, 2 gas injection and 1 water injection)
 

and the laying of a 45-kilometer long underwater pipeline connecting to Kristin. Production start-up is expected in 2009, in coincidence with the production decline of Kristin which will free spare capacity for Tyrihans production.
Exploration Eni holds interests in 27 prospecting Licenses ranging from 5 to 100%, 6 of these are operated. In February 2006, following an international bid procedure, Eni was awarded offshore Block 6607/11-122D (Eni’s interest 20%) in the Halten Terrace basin, near the Maruk discovery (Eni operator with a 20% interest) covering a gross acreage of 7 square kilometers. Eni increased its interests in: (i) PL 211 (Eni’s interest 30%) where the Victoria gas discovery was made, which represents a technological challenge due to high pressure and temperature in the field; (ii) PL 264 (Eni’s interest 40%) where the Hvitveis gas discovery was made.
Exploration yielded positive results in PL 128 (Eni’s interest 11.5%) with a gas discovery and in PL 134 (Eni’s interest 30%) with an oil discovery, with the drilling of an appraisal well of the earlier Morvin discovery.

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BARENTS SEA
Currently Eni is only performing exploration activities in this area. Eni is operator of 2 PLs 201 (Eni’s interest 67%) and 229 (Eni’s interest 65%) and holds interests varying from 15 to 31% in 3 other Licenses. Operations in this area are focused on the appraisal of the mineral potential of the large Goliath discovery made in 2000 at a water depth of 370 meters in PL 229 aimed at its commercial development. In late 2006 five appraisal wells have been successfully drilled and confirmed the presence of hydrocarbons in the Goliath structure at a depth of 1,000-1,800 meters.
In 2006 following an international bid procedure, Eni acquired blocks 7124/6, 7125/4 e 7125/5 in PL393 (Eni’s interest 30%). In 2007 the exploration plan provides for the drilling of one well.

 

United Kingdom
Eni has been present in the United Kingdom since 1964. Eni’s activities are carried out in the British section of the North Sea, in the Irish Sea and in some areas east and west of the Shetland Isles over a gross acreage of 3,680 square kilometers (1,328 net to Eni). In 2006 Eni’s net production of hydrocarbons averaged 141 kboe/d.
Exploration and production activities in the United Kingdom are regulated by concession contracts.
In the medium term, production is expected to decline due to mature field declines.


BRITISH SECTION OF THE NORTH SEA
Production Eni holds interests in 12 production areas in the British section of the North Sea for a total acreage of 1,498 square kilometers. The main fields are Elgin/Franklin (21.87%), the J-Block (33%), the Flotta Catchment Area (20%), Andrew (16.2%) and Farragon (30%) which in 2006 accounted for 57% of Eni’s production in the United Kingdom.
In 2006 production started at the gas and condensate Glenelg field (Eni’s interest 8%) that is connected

 

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to the Elgin/Franklin transport infrastructure and production platform.
This field produced 12 kboe/d (1 net to Eni) in 2006. Other actions in the year concerned optimization of producing fields, in particular MacCulloch, Elgin/Franklin and J-Block through the drilling of additional wells and workover actions for supporting production levels.
Development The main project underway concerns the development of the reserves in the Blane field in Block 30/3a (Eni’s interest 18%). This project provides for the drilling of 3 subsea wells (2 production and 1 water injection) and a linkage to existing treatment facilities. Associated gas will be reinjected in the nearby Ula field reservoir. Start-up is expected in the third quarter of 2007 with an initial flow of 12 kboe/d (2.2 net to Eni).
Exploration Eni holds interests in 32 exploration blocks ranging from 3 to 66%, in 3 of these Eni is operator.
Exploration yielded positive results in permit P/011 Block 30/06a (Eni’s interest 53.9%) with a hydrocarbon discovery and in permit P/672 block 30/02c (Eni’s interest 7%) with an oil discovery that has been linked to the production facilities of the nearby Jade field (Eni’s interest 7%).

IRISH SEA
Production Eni holds interests in 5 production blocks in the Liverpool Bay area (Eni’s interest 53.9%) in the eastern section of the Irish Sea for a total acreage of 222 square kilometers. Main fields are Douglas, Hamilton and Lennox, which in 2006 accounted for 26% of Eni’s production in this area.

SHETLAND ISLES
Production Eni holds interests in 6 production permits located east of the Shetland Isles for a for a total acreage of 644 square kilometers. Main fields are Ninian (Eni’s interest 12.94%) and Magnus (Eni’s interest 5%) which in 2006 accounted for 5% of Eni’s production in the United Kingdom. In 2006 maintenance and optimization actions were performed with the upgrade of the Ninian facility and the drilling of additional wells on Magnus.
Exploration Eni holds interests in 7 exploration blocks ranging from 20 to 38%, where an intense exploration campaign is underway.

Rest of World

Saudi Arabia
Eni entered Saudi Arabia in 2004. Ongoing activities concern exploration of the so called C area in order to discover and develop gas reserves. This license covering 51,687 square kilometers (25,844 net to Eni) is located in the Rub al Khali basin at the border with Qatar and
 


the United Arab Emirates. The exploration plan provides for the drilling of 4 wells in five years. In case of a commercial discovery, the contract will last 25 years with a possible extension to a maximum of 40 years. Any gas discovered will be sold locally for power generation and as feedstock for petrochemical plants. Condensates and NGL will be sold on international markets. Drilling of the first commitment well is underway.

Australia
Eni has been present in Australia since 2000. In 2006 Eni’s net production of oil and natural gas averaged 26 kboe/d. Activities are focused on conventional offshore fields over an area of 24,143 square kilometers (19,910 net to Eni). The main production blocks in which Eni holds interests are WA-25-L (Eni operator with a 65% interest), JPDA 03-13 (Eni’s interest 12.04%), after unitization with JPDA/02-12. Eni is operator with a 100% interest in permits WA-279 P and WA-313-P in the offshore Bonaparte basin, where the Blacktip (under development) and Penguin fields are located.
In the exploration phase Eni is operator with a 67% interest of Block WA-328-P and with a 100% interest

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of blocks TP-22, WA-280-P and WA-326-P.
Exploration and production activities in Australia are regulated by concessions, while in the cooperation zone between East Timor and Australia (JPDA) they are regulated by PSAs.
In the medium term, production is expected to increase due to ongoing development activities.

BLOCK WA-25-L
Production With a total acreage of 400 square kilometers this block is located offshore the Carnavon Basin, north west of Australia at a water depth of 100 meters. The main field is Woollybutt with a production of 10 kbbl/d (6.5 net to Eni) in 2006. The field is operated by an FPSO unit with a 55kbbl/d treatment capacity.
Development The area south of Woollybutt is under development with the linking of two production wells to existing facilities. Start-up is expected in 2008.
Exploration Exploration is intense in order to extend Woollybutt’s production profile. In particular the Woollybutt 5 appraisal well found new oil strata in the southern area of the field.

BLOCK JPDA 03-13
Production With a total acreage of 330 square kilometers this block is located offshore north western Australia at a water depth of 80 meters in the cooperation zone between East Timor and Australia. Production of liquids and gas comes from the Bayu Undan field. Liquid production started in 2004 and is supported by 3 treatment platforms and an FPSO unit for the separate storage of condensates, propane and butane. Production of natural gas is carried by a 500-kilometer long pipeline to the Darwin liquefaction plant which has a capacity of 3.5 mmtonnes/y of LNG (equivalent to approximately 173 bcf/y of feed gas). Unused volumes are reinjected in the field. In February 2006 the first shipment of LNG was made to the Japanese market to two companies operating in power generation and natural gas distribution.
  Total production from Bayu Undan was 182 kboe/d (20 net to Eni) in 2006.

BLOCK WA-279-P
Development In this block with a total acreage of 2,780 square kilometers, the development of the Blacktip field with recoverable reserves of 150 mmboe is underway. This project provides for the drilling of 2 production wells, the installation of a production platform, the laying of a 108 kilometers long pipeline and the construction on land of a treatment plant with a capacity of 46 bcf/y. Natural gas extracted from this field will be used mainly for power generation for the city of Darwin and other centers in the Northern Territory under a 25-year contract signed with Darwin Power & Water Utility Co. Production start-up is expected in 2009 at an initial flow of 2.3 bcf/y, due to increase to 39 bcf/y.

Brazil
In January 2006 following the international bid procedure of October 2005, Eni acquired the operatorship of a six-year exploration license in Block BM-Cal-14, covering an area of over 750 square kilometers in deep and ultradeep waters located in the offshore Camamu-Almada basin.
In November 2006 following an international bid procedure, Eni presented the best offer for the exploration license of of Block S-M-857 (Eni’s interest 100%) with a gross acreage of about 700 square kilometers in the deep offshore of the Santos basin. The assignation of blocks has not yet been completed.

Croatia
Eni has been present in Croatia since 1999. In 2006 Eni’s net production of natural gas averaged 67 mmcf/d. Activities are deployed in the Adriatic offshore facing the city of Pula over an area of 6,056 square kilometers (3,028 net to Eni). Exploration and production activities in Croatia
are regulated by PSA.

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Production Eni through a 50/50 joint venture with INA, the national Croatian oil company, operates the Ivana natural gas field. As part of the development plan of the natural gas reserves in the area, the Ivana C/K platform and the Ika A/B and Ida A fields were started up. Production from these fields is sent to the Ivana K platform, from here to the Garibaldi K platform and sold on the Italian market.
In 2006 the Katarina field (Eni’s interest 50%) has been started up. Production is sent to Italy through the Marica and Barbara T2 platform.
Development The main project underway concerns the Annamaria field (Eni’s interest 50%) and it provides for the installation of 2 production platforms and the linking by a 37-kilometer long pipeline to the Ivana K platform. Start-up is expected for 2009.
Exploration Exploration is focused on the mineral potential of the Ivana permit. In 2006 the Ana 1 and Vesna 1 discovery wells identified gas bearing strata.

India
In 2005, following an international bid procedure Eni obtained an exploration license as operator in Block RJ-ONN-2003/1 (Eni’s interest 34%) and Block AN-DWN-2003/2 (Eni’s interest 40%) located in onshore in Rajasthan in the north-west of India and in the Indian Ocean, near the Andaman Islands, respectively.
The exploration program for Block RJ-ONN-2003/1 provides for the drilling of 4 wells in the first 4 years of the license. Any hydrocarbons discovered will be sold locally.
The exploration program for Block AN-DWN-2003/2 provides for the drilling of 3 wells in the first 4 years of the license. The development of any reserves found provides for the installation of an FPSO unit for liquid production and of facilities for gas treatment.
In February 2007 Eni concluded an agreement with a partner whereby interests in India and Congo were exchanged. Following this transaction Eni acquired a 34% interest in block MN-Dwn-22002/ with high mineral potential in the Indian offshore at a water depth of 2,000 meters with a total acreage of 10,000 square kilometers and will give to its partner a 20% interest in the Mer Très Profonde Nord permit (Eni operator with a 40% interest) offshore Congo.

Iran
Eni has been present in Iran since 1957. In 2006 production net to Eni averaged 29 kboe/d. Eni’s activities are concentrated in the offshore of the Persian Gulf and onshore for a total acreage of 1,456 square kilometers (820 net to Eni).
 

Exploration and production activities in Iran are regulated by buy-back contracts.
Production The main producing fields operated by Eni are South Pars phases 4 and 5 (Eni’s interest 60%) in the offshore of the Persian Gulf and Darquain (Eni’s interest 60%) located onshore which accounted for 89% of Eni’s production in Iran in 2006. In 2006 the onshore gas treatment plant of South Pars was completed and now it can produce 706 bcf/y of natural gas, 1 mmtonnes/year of LPG and 30 mmbbl/y of condensates. Production platforms are linked to the Assaluyeh treatment center by means of two 105 kilometer long pipelines. Eni’s entitlements to the liquid production from this field (22 kbbl/d in 2006) are destined to recover investment expenditure incurred for the field development to remunerate capital employed during an eight-year term in accordance to the existing buy-back contract.
Eni also holds interests in the Dorood (45%) and Balal (45%) oil fields.
Development The main project concerns the second development phase of the Darquain field providing for the drilling of additional wells, the increase of the existing treatment capacity and the injection of gas in the field.

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These actions aim at increasing production from the present 50 kbbl/d to over 160 kbbl/d (14 net to Eni).
In the medium term Eni’s liquid production in Iran is expected to increase due to ongoing development initiatives.

Indonesia
Eni has been present in Indonesia since 2000. Eni’s production in 2006 amounted to 23 kboe/d. Production is concentrated in the western offshore and onshore of Borneo and offshore Sumatra over a total acreage of 28,438 square kilometers (16,301 net to Eni).
Exploration and production activities in Indonesia are regulated by PSA.
Production Production consists mainly of gas and derives from the Sanga Sanga permit (Eni’s interest 37.81%).
This gas is treated at the Bontang liquefaction plant, the largest in the world, and is exported to the Japanese, South Korean and Taiwanese markets. Activities are underway for mitigating the natural decline of production by means of infilling wells.
Exploration Eni holds interest in 11 exploration blocks, 6 as operator with interests ranging from 20% to 100%.
An intense exploration campaign is underway in the Tarakan basin offshore Borneo.

Kazakhstan
Eni has been present in Kazakhstan since 1992.
Main activities are performed in the Karachaganak field onshore in western Kazakhstan and in the area covered by the North Caspian Sea PSA in the shallow waters of the Northern Caspian Sea.
Eni is co-operator with British Gas with a 32.5% interest of the Karachaganak oil, gas and condensate field. In 2006 production from this field (net to Eni) averaged 64 kbbl/d of liquids and 6.4 mmcm/d of natural gas, totalling 103 kboe/d. This field is developed by producing liquids (oil and condensates) from the deeper layers of the reservoir and reinjecting the associated gas in the higher layers. This scheme enables to increase the recovery of liquids.
Approximately two thirds of liquid production are stabilized at the Karachaganak Processing Complex (KPC) with a capacity of 150 kbbl/d and exported to Western markets, most of it through the Caspian Pipeline Consortium pipeline (Eni's interest 2%) linked to the field by a 635-kilometer long pipe, while the rest flows though the Atyrau-Samara pipeline from 2006. The remaining third of non stabilized liquid production and the associated gas not reinjected are marketed at the Russian terminal in Orenburg. Field activities in 2006 concerned: (i) the sanctioning of the
  expansion of stabilization capacity (4th train) which will enable to further increase exported volumes entailing the achievement of better realization prices with respect to the sale on local Russian markets; (ii) the continuation of activities required for keeping production plateau at the current levels, in particular by drilling new wells. Studies are underway for designing a further development phase, as provided for in the PSA governing activities at this field, aimed at monetizing reserves of gas and associated liquids through the signing of gas sale contracts with Russian and Kazakh companies and the construction of a gas treatment plant.
As part of the North Caspian Sea PSA, Eni with an 18.52% interest is single operator of the development of the Kashagan field, which is believed to be the most important discovery in the world in the past thirty years. The development plan sanctioned in February 2004 envisages field development through three phases aiming at producing from 7 to 9 bbbl of gross recoverable reserves, extendible to 13 bbbl through partial gas reinjection.
The development plan of this field provides for the construction of production hubs located on platforms and artificial islands which will collect production from satellite islands from which production wells will be drilled. Oil and non reinjected gas will be treated in the hubs and delivered, through two separate lines, to onshore treatment plants (located at Bolashak, near Atyrau). The oil will be further stabilized and purified; natural gas will be treated for the removal of hydrogen sulphide and will be mostly used as fuel for the production plants.
The remaining amounts will be marketed.
The first development phase is progressing leveraging on the use of the most advanced techniques in order to cope with high pressures in the reservoir, the presence of high concentration of hydrogen sulphide and harsh environmental conditions. By the end of 2006, works had been completed corresponding to 59% of the initial scope, with the total amount of contracts awarded at $10.6 billion. Drilling activities and completion of development wells from the two artificial islands already installed have been progressing. In addition, three rigs, two of which being of the most advanced class, were installed on said islands. Three development wells were completed yielding high rates of productivity under test phase.
Production start-up is currently scheduled for the third quarter of 2010 as compared to an initial forecast indicating a start-up in 2008, due also to the need on the part of Eni to perform certain studies to define measures intended to enhance the overall level

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of safety and operability of facilities. As a result of said reconfiguration completed by year-end, the onshore design has been confirmed, while certain enhancements have been identified offshore which do not alter the original development concept.
These enhancements are expected to be included in the development plan and implemented.
Estimated capital expenditure to reach the 300 kbbl/d production target in first development phase stands currently at $19 billion. The cost increase over the approved budget of $10.3 billion in real terms 2007, was driven by: (i) the effect of exchange rates that caused a cost increase of materials and services in the oil industry; (ii) an underestimation of costs to conduct offshore operations in shallow/ultra shallow waters due to a lack of benchmarks, also reflecting technical and logistic issues and environmental constraints; (iii) the enhancements to the original layout of offshore facilities.
Based on the high level of productivity yielded by the first three development wells, management currently

  expects a full field production plateau of 1.5 mmbl/d, representing a 25% increase from the original target envisaged by the development plan.
Capital expenditure amounts indicated above do not include the capital expenditure for the construction of the infrastructure for exporting production to international markets, for which various options are under scrutiny by the consortium. These include: (i) the use of existing infrastructure, such as the Caspian Pipeline Consortium pipeline (Eni's interest 2%) and the Atyrau-Samara pipeline; (ii) the laying of a new pipeline according to two different options. The first one envisages laying of a line connecting the Bolashak production centre with the Baku-Tbilisi-Cehyan pipeline (Eni's interest 5% corresponding to the right to transport up to 50 kbbl/y). The second option envisages laying of a pipeline designed to bypass the Turkish Straits of Bosporus and Dardanelles, enabling delivery of oil produced in the Caspian region to the Ceyhan commercial hub on the Mediterranean coast. Following award of the relevant license to the Turkish company Çalik Enerji, partnering Eni in this initiative (both with a 50% stake), engineering activities have been started in the second half of 2006. This new

infrastructure is expected to be 550-kilometers long with a maximum transport capacity of 1 mmbbl/d of oil, expandable to 1.5 mmbbl/d.
Evaluation activities of other discoveries made in the contractual area covered by the North Caspian Sea PSA made some good progress. A first appraisal well of the Kairan discovery was successfully drilled.
Drilling of a second appraisal well of the Kalamkas discovery yielded productive results that emphasize the good productivity of the reservoir and a much larger extension of said discovery as compared to the initial estimate.

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In the medium term Eni's production in Kazakhstan is expected to grow due to the contribution of increased gas volumes produced at Karachaganak and the start up of Kashagan.


Mozambique
In March 2006, following an international bid tender, Eni obtained the exploration license for Area 4, located in the deep offshore of the Rovuma Basin. This block covers a gross area of 17,646 square kilometers in an unexplored geological basin with great mineral potential according to surveys performed. In December 2006, Eni signed the relevant exploration contract.

Pakistan
Eni has been present in Pakistan since 2000. In 2006 production net to Eni averaged 51 kboe/d. Eni's main activities are located onshore covering a total acreage of 29,790 square kilometers (20,965 net to Eni).
Exploration and production activities in Pakistan are regulated by concessions (onshore) and PSA (offshore).
In the medium term Eni's production in Pakistan is expected to increase.
Production Eni's main permits are Bhit (Eni operator with a 40% interest), Sawan (23.68%) and Zamzama (17.75%), which in 2006 accounted for 86% of Eni's production in Pakistan. Activities concerned optimization of producing

  fields, in particular Sawan, Kadanwari, Miano and Bhit by means of drilling additional wells and workover aimed at maintaining production levels.
Development The main project underway, sanctioned in 2006, concerns the Bhit permit for the construction of a third treatment train at the existing terminal which will make available also the production from the nearby Badhara field. A study is underway for the construction of a compression station at Bhit. Work continued in the Zamzama permit for the construction of a new treatment plant for the production of HVC gas. Also a compression station at Sawan is under study.
Exploration Eni holds interests in 11 exploration blocks ranging from 30 to 100%.
In 2006 following an international bid procedure Eni was awarded the operatorship of four exploration licenses relating to Block Rjar/Mithi, Thar and Umarkot. These blocks are located in the East Sindh and cover a gross area of about 9,950 square kilometers. The exploration plan provides for the drilling of a well in each block in the first year and the completion of seismic surveys. In the Bhit permit seismic surveys were completed in the year. Exploration activity is intense in the offshore.

 

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United States
Eni has been present in the United States since 1966.
In 2006 Eni's oil production averaged 32 kboe/day. Activities are performed in the conventional and deep offshore in the Gulf of Mexico and onshore and offshore Alaska over a total acreage of 7,803 square kilometers (3,758 net to Eni). Exploration and production activities in the United States are regulated by concessions.
In the medium term Eni's production is expected to remain stable.

GULF OF MEXICO
Production Eni holds interests in 24 production blocks in the deep and conventional offshore covering a total acreage of 803 square kilometers. The main fields are Allegheny (Eni operator with an 86% interest), Medusa (Eni's interest 22%), Europa (Eni's interest 28%), King Kong (Eni operator with a 49% interest), East Breaks (Eni operator with an 84% interest) and Morphet (Eni operator with an 84% interest). These fields accounted for 81% of Eni's production in 2006. In 2006 the Allegheny South
  (Eni's interest 100%) and North Black Widow (Eni's interest 25.19%) fields have been started-up. Production from Allegheny South reached 3 kbbl/d 18 months after its discovery.
Exploration Eni holds interests in 76 exploration permits varying from 5 to 100%. In 19 of these Eni is operator. Exploration yielded positive results in: (i) Green Canyon Block 473 (Eni operator with a 50% interest), where the presence of oil was confirmed; (ii) Mississippi Canyon Block 502 (Eni's interest 100%), the Longhorn North discovery well showed the presence of natural gas. A feasibility study to develop this discovery is underway.

ALASKA
Eni's activities in Alaska are currently in the exploration and development phase. In November 2006, Eni started an exploration campaign in the onshore Rock Flour area (Eni's interest 100%). The approved plan provides for the drilling of three wells. In March 2006, following an international bid procedure, Eni was awarded 11 exploration blocks near Rock Flour.

 

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Overall Eni holds interests in 151 blocks ranging from 10 to 100%, in over half of these is operator.
Eni signed an agreement with a partner for a swap of interests in 64 exploration blocks (Eni's interest 60%) located in the Beaufort Sea, offshore North Alaska. Based on this agreement, Eni is entitled to 140 exploration blocks (50% of which operated). Exploration plans provide for 3D seismic surveys and drilling of an exploration well by 2010.
Development The main development plan concerns the offshore Oooguruk field (Eni's interest 30%) in the Beaufort Sea with recoverable reserves of 301 mmboe. The project provides for the beginning of production of the Kuparuk C and Nisquit areas. In the first area the plan provides for the drilling of 5 wells (3 production and 2 water injection). For the second area the plan provides for the drilling of 33 wells (18 production and 15 water/gas injection). Production is expected to start at the end of 2007 peaking at 17 kboe/d (5.4 net

  to Eni) in 2010 and to be sent to the DS-3H onshore plant. In January 2007 Eni signed an agreement for the purchase of the remaining 70% interest in the Nikaitchuq field, where it already holds a 30% interest.
Drilling activities are underway. The project is expected to yield approximately 100 mmboe when started-up in late 2009.

East Timor
In May 2006 following an international bid procedure Eni was awarded the operatorship of five exploration licenses (Eni's interest 100%) covering contract areas A, B, C, E and H with a gross acreage of about 12,183 square kilometers located in the deep offshore between the Timor Island and the international cooperation zone between East Timor and Australia. Relevant Production Sharing contracts were signed.

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  Liquids reserves
by geographic area
 

(mmbbl)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

(at December 31)                                        
Italy   360   329   328   296   309   255   252   225   228   215
North Africa   985   1,024   1,071   1,039   1,171   1,072   1,080   993   979   998
West Africa   728   790   900   934   976   1,022   1,038   1,056   942   793
North Sea   428   433   417   455   552   498   529   450   433   386
Rest of World   343   305   421   698   940   936   1,239   1,284   1,191   1,089
Total outside Italy   2,484   2,552   2,809   3,126   3,639   3,528   3,886   3,783   3,545   3,266
    2,844   2,881   3,137   3,422   3,948   3,783   4,138   4,008   3,773   3,481

 

  Natural gas reserves by
geographic area
 

(bcf)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

(at December 31)                                        
Italy   7,207   6,977   6,439   6,125   5,640   5,295   4,166   3,818   3,676   3,391
North Africa   3,154   3,834   4,504   5,152   5,509   5,563   5,467   6,453   6,132   5,963
West Africa   721   696   964   922   925   1,533   1,656   1,729   1,967   1,929
North Sea   1,312   1,349   1,331   1,418   1,892   1,899   2,223   2,051   1,864   1,697
Rest of World   274   659   427   1,155   3,106   4,339   4,496   4,384   3,952   3,985
Total outside Italy   5,461   6,538   7,226   8,647   11,432   13,334   13,842   14,617   13,915   13,574
    12,668   13,515   13,665   14,772   17,072   18,629   18,008   18,435   17,591   16,965

 

 

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  Net proved hydrocarbon reserves by geographic area  

(mmboe)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

(at December 31)                                        
Italy   1,646   1,574   1,477   1,389   1,315   1,199   996   890   868   805
North Africa   1,530   1,686   1,849   1,929   2,122   2,033   2,024   2,117   2,047   2,037
West Africa   852   910   1,067   1,093   1,136   1,287   1,324   1,357   1,285   1,129
North Sea   655   666   646   700   879   825   912   807   758   682
Rest of World   390   419   495   897   1,477   1,686   2,016   2,047   1,879   1,783
Total outside Italy   3,427   3,681   4,057   4,619   5,614   5,831   6,276   6,328   5,969   5,631
    5,073   5,255   5,534   6,008   6,929   7,030   7,272   7,218   6,837   6,436

 

  Liquids production
by country
 

(kbbl/d)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                         
Italy   105   100   88   76   69   86   84   80   86   79
North Africa   212   213   221   227   228   252   250   261   308   329
     Egypt   75   88   109   112   97   97   92   94   90   85
     Libya   103   92   80   82   84   79   82   89   120   144
     Algeria   20   19   18   21   35   65   65   66   86   88
     Tunisia   14   14   14   12   12   11   11   12   12   12
West Africa   177   194   202   213   219   222   236   285   310   322
     Nigeria   77   68   65   75   84   83   108   134   123   106
     Angola   55   58   59   63   64   62   58   78   122   151
     Congo   45   67   75   72   69   75   68   72   65   65
     Gabon       1   3   3   2   2   2   1        
North Sea   114   112   116   124   204   213   235   203   179   178
     Norway   45   47   52   65   70   74   105   102   96   98
     United Kingdom   69   65   64   59   134   139   130   101   83   80
Rest of World   38   34   47   108   137   148   176   205   228   171
     Venezuela                   39   42   54   67   61   15
     Kazakhstan   16   12   19   27   23   32   41   54   64   64
     United States   6   4   5   38   26   29   25   25   19   21
     Australia                           14   21   21   18
     Ecuador           2   22   25   22   21   19   17   15
     Iran                       3   9   9   35   29
     China   13   12   14   14   12   10   7   5   7   6
     Indonesia                   6   5   5   4   3   2
     Pakistan                               1   1   1
     Qatar   3   6   7   7   6   5                
Total outside Italy   541   553   586   672   788   835   897   954   1,025   1,000
    646   653   674   748   857   921   981   1,034   1,111   1,079

 

 

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Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

  Natural gas production by country (1)  

(mmcf/d)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       1,677.5   1,649.2   1,515.0   1,440.9   1,338.4   1,289.0   1,211.3   1,098.3   1,002.9   907.6
North Africa       98.9   134.2   279.0   455.6   515.7   589.8   586.3   681.6   988.8   1,299.6
     Egypt       98.9   134.2   279.0   445.0   480.3   550.9   550.9   607.4   706.3   812.3
     Libya                       17.7   21.2   10.6   45.9   254.3   452.0
     Algeria                               7.1   17.7   14.1   21.2
     Tunisia                   10.6   17.7   17.7   17.7   10.6   14.1   14.1
West Africa       17.7   10.6   24.7   63.6   81.2   88.3   137.7   176.6   190.7   282.5
     Nigeria       17.7   10.6   24.7   63.6   81.2   88.3   137.7   155.4   165.9   247.2
     Angola                                   10.6   17.7   24.7
     Congo                                   10.6   7.1   10.6
North Sea       229.5   254.2   218.9   254.3   487.3   550.9   639.2   603.9   600.4   596.8
     United Kingdom       127.1   183.6   180.1   197.8   395.5   423.8   416.7   360.2   243.7   353.1
     Norway       102.4   70.6   38.8   56.5   81.2   116.5   215.4   236.6   356.7   243.7
     Netherlands                       10.6   10.6   7.1   7.1        
Rest of World       91.8   127.2   173.0   279.0   497.9   628.6   752.2   826.3   812.3   879.3
     Pakistan                       10.6   38.8   162.4   257.5   275.5   289.6
     Kazakhstan           63.6   102.4   134.2   109.5   151.9   162.4   194.2   222.5   229.5
     Indonesia                       236.6   226.0   208.4   173.0   137.7   116.5
     United States       91.8   63.6   70.6   134.2   116.5   173.0   134.2   109.5   74.2   63.6
     Trinidad & Tobago                           10.6   56.5   56.5   56.5   53.0
     Croatia                   10.6   24.7   28.3   28.3   35.3   42.4   67.1
     Australia                                       3.5   49.4
     China                                           10.66
Total outside Italy       437.9   526.2   695.6   1,052.5   1,582.1   1,857.6   2,115.4   2,288.4   2,592.2   3,058.3
        2,115.4   2,175.4   2,210.6   2,493.4   2,920.5   3,146.6   3,326.7   3,386.7   3,595.1   3,965.9
     
(1)   Includes natural gas consumed in operations (283, 247, 212 mmcf/d, in 2006, 2005 and 2004, respectively).

 

 

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Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

  Hydrocarbon production by country (1)  

(kboe/d)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       403   394   358   333   308   316   300   271   261   238
North Africa       229   236   269   306   317   354   351   380   480   555
     Egypt       92   111   157   189   180   192   187   200   213   227
     Libya       103   92   80   82   87   83   84   97   164   222
     Algeria       20   19   18   21   35   65   66   68   88   91
     Tunisia       14   14   14   14   15   14   14   15   15   15
West Africa       180   196   206   224   233   237   260   316   343   372
     Nigeria       80   70   69   86   98   98   132   161   152   149
     Angola       55   58   59   63   64   62   58   80   124   156
     Congo       45   67   75   72   69   75   68   74   67   67
     Gabon           1   3   3   2   2   2   1        
North Sea       155   156   154   168   288   308   345   308   283   282
     United Kingdom       92   97   95   93   202   212   202   164   145   142
     Norway       63   59   59   75   84   94   142   143   138   140
     Netherlands                       2   2   1   1        
Rest of World       54   56   77   156   223   257   306   349   370   323
     Kazakhstan       16   23   37   50   42   58   69   88   102   103
     Venezuela                       39   42   54   67   61   15
     Pakistan                       4   7   28   46   49   51
     United States       22   15   17   61   46   59   48   44   33   32
     Indonesia                       47   44   41   34   27   23
     Australia                               14   21   22   26
     Ecuador               2   22   25   22   21   19   17   15
     Trinidad & Tobago                           2   10   10   10   9
     Iran                           3   9   9   35   29
     Croatia                   2   2   5   5   6   7   12
     China       13   12   14   14   12   10   7   5   7   8
     Qatar       3   6   7   7   6   5                
Total outside Italy       618   644   706   854   1,061   1,156   1,262   1,353   1,476   1,532
        1,021   1,038   1,064   1,187   1,369   1,472   1.562   1,624   1,737   1,770
     
(1)   Includes natural gas consumed in operations (283, 247, 212 mmcf/d in 2006, 2005 and 2004, respectively).

 

 

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Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

  Hydrocarbon production sold  

(mmboe)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                                                 
Hydrocarbon production       372.5     378.8     388.4     434.5     499.7     537.3     570     594.6     634.2     645.9  
Over/under lifting and change in inventories       (1.4 )   (3.3 )   (1.5 )   (1.9 )   (3.1 )   (4.0 )   (4.3 )   (4.2 )   (3.1 )   (2.4 )
Withdrawals from (input to) natural gas storage       (1.0 )   6.9     6.7     (4.6 )   9.1     (1.8 )                        
Own consumption of gas                               (6.0 )   (8.4 )   (9.5 )   (13.9 )   (16.2 )   (18.4 )
Hydrocarbon production sold       370.1     382.4     393.6     428.0     499.7     523.1     556.2     576.5     614.9     625.1  
oil   (mmbbl)   234.3     234.86     244.53     272.45     310.69     333.40     354.10     375.40     402.60     391.07  
- of which to R&M Division       89.30     93.79     202.29     214.42     216.38     242.89     247.87     260.83     267.37     267.84  
natural gas   (bcm)   21.69     23.58     23.89     25.03     30.50     30.68     32.73     32.89     34.53     38.05  
- of which to G&P Division       16.87     17.76     16.24     13.70     14.39     13.69     14.07     13.16     10.67     15.11  

 

- 39 -


Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

Principal oil and natural gas interests at December 31, 2006
   

Commencement of operations

 

Number of interests

 

Gross exploration and development acreage (1)

 

Net exploration and development acreage (1)

 

Net development acreage (1)

 

Type of fields/ surface

 

Number of producing fields

 

Number of other fields

                                 
Italy   1926   171   28,508   22,496   12,743   Onshore/Offshore   90   89
Outside Italy       858   673,631   362,723   35,530   Onshore/Offshore   365   174
North Africa                                
     Algeria   1981   36   12,739   3,456   861   Onshore   26   12
     Egypt   1954   53   23,214   13,901   2,401   Onshore/Offshore   37   30
     Libya   1959   17   39,569   34,113   12,783   Onshore/Offshore   11   15
     Tunisia   1961   14   6,464   2,274   1,223   Onshore/Offshore   13   4
        120   81,986   53,744   17,268       87   61
West Africa                                
     Angola   1980   49   18,776   3,275   1,099   Offshore   39   30
     Congo   1968   20   9,797   4,169   880   Offshore   17   7
     Nigeria   1962   49   43,215   7,356   5,715   Onshore/Offshore   122   23
        118   71,788   14,800   7,694       178   60
North Sea                                
     Norway   1965   47   18,851   7,077   123   Offshore   9   6
     United Kingdom   1964   75   5,860   1,328   688   Offshore   33   13
        122   24,711   8,405   811       42   19
Rest of World                                
     Australia   2001   13   24,143   19,910   2,279   Offshore   2   1
     Brazil   1999   3   2,948   2,802       Offshore        
     China   1983   4   866   181   103   Offshore   9   4
     Croatia   1996   3   6,056   3,028   987   Offshore   5   5
     East Timor   2006   5   12,224   12,224       Offshore   5   5
     Ecuador   1988   1   2,000   2,000   2,000   Onshore   1   1
     India   2005   2   14,445   5,698       Onshore/Offshore        
     Indonesia   2001   13   28,438   16,301   656   Onshore/Offshore   7   8
     Iran   1957   4   1,456   820   820   Onshore/Offshore   4    
     Kazakhstan   1995   6   4,934   960   489   Onshore/Offshore   1   5
     Pakistan   2000   18   29,790   20,965   615   Onshore/Offshore   6   1
     Saudi Arabia   2004   1   51,687   25,844       Onshore        
     Trinidad & Tobago   1970   1   382   66   66   Offshore   3   2
     United States   1968   391   7,803   3,758   560   Onshore/Offshore   20   5
     Venezuela   1998   4   1,958   790   66   Offshore       1
        469   189,130   115,347   8,641       58   33
Other countries       9   6,311   1,240   1,116   Offshore       1
Other countries with onlyexploration activity       20   299,705   169,187       Onshore/Offshore        
Total       1,029   702,139   385,219   48,273       455   263
     
(1)   Square kilometers.

- 40 -


Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

  Exploration wells  

(unit)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Wells drilled       127   121   60   95   110   120   105   66   52   68
     Outside Italy       98   82   43   75   99   111   97   60   50   64
     Italy       29   39   17   20   11   9   8   6   2   4
Wells drilled (net to Eni)       74   66   29   47   47   52   43   30   22   36
     Outside Italy       52   35   16   30   37   45   36   26   20   32
     Italy       22   31   13   17   10   7   7   4   2   4
                                             
SEC Criteria                                            
Wells drilled       95   122   65   72   85   83   107   71   56   61
Total successful wells       39   54   32   24   31   32   50   37   22   26
Total success rate   (%)   41.1   44.3   49.2   33.3   36.5   38.6   46.7   52.1   39.3   42.6
Wells drilled (net to Eni)       62   68   31   40   40   43   47   32   24   32
Total successful wells (net to Eni)       27   32   12   12   13   17   22   19   12   16
Total success rate (net to Eni)   (%)   43.3   47.0   38.0   30.6   31.3   39.1   45.7   57.3   47.4   49.2

 

  Reserve life index  

(year)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       11.5   10.2   10.7   11.7   10.9   10.8   9.0   8.8   9.2   9.3
North Africa       18   19.3   18.6   17.5   18.4   15.8   15.9   15.5   11.7   10.0
West Africa       12.8   12.4   14.6   13.3   13.4   14.8   13.9   11.7   10.2   8.3
North Sea       11   11.7   12.0   11.4   8.4   7.4   7.2   7.2   7.3   6.6
Rest of World       19.7   20.9   16.8   15.6   18.0   17.1   18.1   16.1   13.9   15.1
        13.6   13.4   14   14   13.7   13.2   12.7   12.1   10.8   10.0

 

  Reserve replacement ratio (1)  

(%)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       106   53   30   26   39   -   -   -   77   28
North Africa       229   277   265   172   267   30   93   168   60   95
West Africa       107   179   312   132   151   273   138   128   42   ..
North Sea       120   119   113   185   271   53   168   6   53   26
Rest of World       1,410   245   196   825   818   324   396   124   ..   18
        207   147   171   210   282   119   142   91   40   38
     
(1)   All sources.

- 41 -


Contents

ENI FACT BOOK / EXPLORATION & PRODUCTION - MAIN DATA

 

  Economic indicators per boe  

(USD/boe)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Revenues       19.02   13.68   16.95   24.67   21.52   22.07   24.82   31.22   41.97   49.68
Lifting cost (1)       3.98   3.56   3.64   3.75   4.02   3.87   4.09   4,8   5.45   5.62
Income       3.86   0.13   4.11   7.86   5.48   5.08   5.95   8.87   12.2   14.97
Exploration cost (three-year average) - discovery cost (2)       1.67   1.78   1.77   1.7   1.55   1.38   1.21   1.21   1.67   2.86
Finding and development cost (three-year average) (3)       4.72   5.16   5.43   5.35   5.33   5.67   6.53   7.26   10.72   13.87
     
(1)   Ratio of production costs (incurred for well and facilities maintenance and royalties) and volumes produced.
(2)   Exploration cost for each boe of new reserves discovered or proved is calculated as ratio of costs incurred with respect to exploration activity and purchase of unproved property to additions to proved reserves related to improved recovery, extensions and new discoveries and revisions of previous estimates. Starting in 2001 averages were calculated excluding purchase costs of unproved property of Lasmo in 2001 and of Fortum Petroleum in 2003.
(3)   Finding and development cost for each boe of new reserves discovered or proved is calculated as ratio of costs with respect to exploration and development activities and purchase of unproved property to additions to proved reserves related to improved recovery, extensions and new discoveries and revisions of previous estimates. In order to allow for an homogeneous comparison the following adjustments were carried out: (i) averages for the 2001-2005 period were calculated with the exclusion of the purchase cost of unproved property of Lasmo (purchased in 2001) and Fortum Petroleum (purchased in 2003); (ii) averages for the 2002-2006 period were calculated with the exclusion of development costs related to Iranian buy-back contracts; (iii) averages in the 2003-2006 period were calculated with the exclusion of estimated costs for asset retirement obligations. Following the Statement of Financial Accounting Standard No. 143 - Accounting for Asset Retirement Obligations - these costs are capitalized when the related capital expenditure is incurred; further adjustments of previous estimates are recognized whenever an estimate needs to be updated.

 

  Capital expenditure  

(million euro)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Exploration       677   755   636   811   757   902   635   499   656   1,348
     Italy       178   191   132   156   80   66   59   51   38   128
     Outside Italy       499   564   504   655   677   836   576   448   618   1,220
Acquisition of proved and unproved property       95   103   752   416   67   317   30       301   152
     Italy       48       54       13                   139
     Outside Italy       47   103   698   416   54   317   30       301   13
Development and capital goods       1,550   2,024   1,880   2,312   3,452   4,396   5,016   4,354   4,008   3,703
     Italy       581   507   435   543   600   442   469   390   414   409
     Outside Italy       969   1,517   1,445   1,769   2,852   3,954   4,547   3,964   3,594   3,294
        2,322   2,882   3,268   3,539   4,276   5,615   5,681   4,853   4,965   5,203

- 42 -


Contents

ENI FACT BOOK / GAS & POWER

                 
  Key performance indicators  

2004

 

2005

 

2006

 
  Net sales from operations (a)  

(million euro)

 

17,302

 

22,969

 

28,368

 
  Operating profit      

3,428

 

3,321

 

3,802

 
  Adjusted operating profit      

3,448

 

3,531

 

3,882

 
  Adjusted net profit      

2,290

 

2,552

 

2,862

 
  Capital expenditure      

1,451

 

1,152

 

1,174

 
  Adjusted capital employed, net      

18,383

 

18,898

 

18,864

 
  ROACE adjusted  

(%)

 

12.6

 

13.7

 

15.1

 
  Worldwide gas sales  

(bcm)

 

87.03

 

94.21

 

97.48

 
  Total gas sales in Europe      

85.32

 

92.50

 

95.97

 
  - G&P division sales      

80.62

 

87.99

 

91.90

 
  - Upstream sales (b)      

4.70

 

4.51

 

4.07

 
  Customers in Italy  

(million units)

 

5.95

 

6.02

 

6.54

 
  Gas volumes transported in Italy  

(bcm)

 

80.41

 

85.10

 

87.99

 
  Electricity production sold  

(terawatthour)

 

13.85

 

22.77

 

24.82

 
  Employees at year end  

(units)

 

12,843

 

12,324

 

12,074

 
       
  (a)   Before elimination of intersegment sales.
  (b)   Does not included Eni’s share of sales made by Nigeria LNG (Eni’s share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006 respectively.
       

- 43 -


Contents

ENI FACT BOOK / GAS & POWER - STRATEGIES

STRATEGIES
Eni Gas & Power division covers all phases of the gas value chain: supply, transport, distribution and marketing, resulting in a fully integrated business model. A significant installed power generation capacity enables Eni to extract further value from gas, diversifying its commercial outlets.
The main feature of the Gas & Power division is its ability to generate a steady stream of earnings and cash flow, leveraging on its unparalleled asset base. Eni boasts market leadership in Europe owing to a solid competitive position thanks to gas availability under long-term supply contracts and equity gas, access to infrastructure, long-term relationships with key producing countries, market knowledge and a wide portfolio of clients. These assets provide Eni with a solid platform for growth. Integration with upstream operations provides the Group with the ability to monetize its equity gas reserves and to pursue opportunities arising in the gas market. Eni’s key target for its Gas & Power division is to generate a free cash flow1 level of euro 2.1 billion in 2010, resulting in a 3% average rate of growth from 2006.
The strategic guidelines to attain this target are as follows:

 

 

     
(1)   Cash flow provided by operating activities less cash outflows for investing activities.

- 44 -


Contents

ENI FACT BOOK / GAS & POWER - HIGHLIGHTS

2006 Highlights

In November 2006, Eni and Gazprom signed a broad strategic agreement. This agreement strengthens a long term partnership between the two companies and represents a fundamental step towards the security of energy supplies to Italy. Key features of this deal are the extension of the duration of Gazprom gas supply contracts to Eni until 2035, further strengthening Eni’s supply portfolio and the pursuing of joint initiatives in the upstream sector. Gazprom is expected to enter the Italian market by selling volumes of gas starting in 2007. Gazprom will obtain the availability of such volumes by means of a corresponding reduction in volumes previously supplied to Eni.

The Gas & Power business confirmed its ability to generate strong and stable performances. The adjusted net profit rose euro 310 million to euro 2,862 million compared to 2005 (up 12.1%) reflecting primarily higher selling margins on natural gas sales in a favorable market scenario, a lower impact of Resolution No. 248/2004 of the Italian Authority for Electricity and Gas, a growth in natural gas volumes sold, volumes transported for the coming on line of the GreenStream gasline and electricity production sold.

Return on average capital employed was 15.1% on an adjusted basis in 2006 (13.7% in 2005).
  Capital expenditure totaled euro 1,174 million and related essentially to development and maintenance of Eni’s transport and distribution networks in Italy, the finalization of the upgrading plan of electricity generation capacity and the start up of the upgrading plan of import gaslines.

Natural gas sales were up approximately 4% to 97.48 bcm primarily reflecting a growth in sales in a number of target European markets (up approximately 16% in particular in Turkey, Germany/Austria, France) also for the build-up of supplies of natural gas from Libya, partly offset by a decrease in sales in Italy due to mild weather conditions in the fourth quarter of the year.

Electricity production sold was 24.82 terawatthour, up 9% from 2005, due to new generation capacity coming on stream.

As a part of its development strategy of the natural gas distribution and sale businesses by means of regional alliances, Eni and its local authority partners defined the Toscana project with the establishment of a regional distribution company managed by Eni and boasting 1.6 million users and a regional selling company controlled by Eni boasting 600 k clients and 1.1 bcm of annual sales.

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THE GAS SYSTEM

The gas supply, transport and marketing sector is experiencing far-reaching developments due to the increasing role of gas in satisfying global energy needs. Key reasons driving gas demand trends are: (i) continuing improvements in technologies applicable to all phases of the natural gas chain capable of reducing distances between production sites and consumption areas (LNG, GTL - gas to liquids, TAP - high pressure transport); (ii) the large amount of gas reserves; (iii) the higher environmental compatibility of natural gas as compared to other hydrocarbons in particular in the generation of electricity, along with expected increasingly tight regulations on emissions mainly due to the implementation of the Kyoto protocol; (iv) the increasingly wide adoption of the combined cycle as elective technology in power generation, based on lower investment costs, higher efficiency and lower emissions than other fuel based technologies; (v) economic, demographic and social development.
In Europe (OECD) demand for gas is expected to grow by 40% by 2020 at an average annual rate of 2-3%, reflecting wider use of gas in power generation and new demand from the fastest growing countries.
The relationship of developments and dynamics of demand and supply of natural gas forces operators in this business to adopt an international approach in planning flows of available supplies and uses, targeting long-term strategies in order to be able to adapt to the changes induced by the evolution of competition, for which an upgrading of infrastructure will prove crucial.

A growing portion of European gas requirements is expected to be satisfied by imports via gasline, mainly from Russia, Algeria, Norway and Libya, taking account of the expected decline in European gas reserves. LNG will play an increasingly important role in satisfying European needs, with an expected 10% annual growth rate over the next four years.
  The Italian natural gas market, third in size in Europe after the UK and Germany, is part of the structural change ongoing in Europe which will lead to the creation of a single energy market. In this context, Italy will be able to exploit is geographic location both as concerns the internal European market and the Mediterranean area.

In 2006 gas consumption in Italy amounted to 84.4 bcm, down 2.2% from 2005; about 87% of gas requirements were met through imports and 13% was covered by domestic production. Eni expects natural gas consumption in Italy to increase with a compound average growth rate of about 2.5% over the next ten years, hitting approximately 106 bcm in 2015, mainly driven by an increased use in power generation, expected to outpace demand growth in other sectors, such as large industrial users, residential space heating in households and services, commercial and small businesses.
Growing gas needs will be met by an increase in imported volumes, which will be supported by significant capital expenditure plans to build new or upgrade existing infrastructure, either under construction or announced.

 

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Activities

1. Marketing and supply of gas

Overview
In 2006, Eni’s worldwide gas sales were 97.48 bcm (including upstream sales) up 3.27 bcm from 2005, or approximately 4%. In the medium term, Eni plans to increase worldwide sales targeting a volume of 105 bcm by 2010, corresponding to a 2.5% average growth rate over the 2007-2010 four-year period.
To enhance its leadership on European markets, Eni will leverage on its strengths represented by gas availability both as equity gas and under long-term purchase contracts, operational flexibility ensured by the access to a wide-reaching transport network, regasification terminals and logistic assets, a large portfolio of clients and market knowledge.
  1.1 Marketing in Italy

MARKET
In 2006 Eni’s gas sales in Italy amounted to 57.09 bcm (including own consumption2), down 1.7% from 2005 due mainly to mild climate conditions in the fourth quarter of the year. This decline was partly offset by an increase in own consumption for power generation.
The Italian market includes three groups of clients: industrial, residential and power generation users; they are further grouped as follows: (i) large industrial clients and power generation utilities directly linked to the national and the regional natural gas networks; (ii) the retail market which is composed of residential and commercial clients (households, commercial users, hospitals, schools, etc.), and small businesses located in urban centers supplied by wholesalers through low pressure distribution networks; and (iii) wholesalers, mainly local selling companies and distributors of natural

 

     
(2)   In accordance with Article 19, paragraph 4 of Legislative Decree No. 164/2000 the volumes of natural gas consumed in own operations by a company or its subsidiaries are excluded from the calculation of ceilings for sales to end customers and for volumes input into the Italian network to be sold in Italy.

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gas for automotive use purchasing natural gas to sell it to final clients.
At December 31, 2006, Eni boasts 6.54 million of clients, of which 6.10 million are retail customers.
In the medium term, in an increasingly competitive market, Eni intends to maintain margins and sales volumes by leveraging on the expected growth of gas demand, maximizing the value of the gas chain focusing in particular on the most profitable clients, deploying a commercial offer tailored on client needs in terms

  of pricing and quality of services, and boosted by the expected development of the combined offer of gas and electricity (“dual offer”).
Eni targets sales volumes of at least 50 bcm in 2010.
This target takes account of the expected increase in competitive pressure due to new supplies coming on the Italian gas market in view of the implementation of the upgrading plans of the import infrastructure to Italy, already underway or announced.

In fact, import capacity is expected to increase by approximately 21 bcm by 2010, of these 13 bcm pertain to Eni’s ongoing upgrading program of its import infrastructure from Russia and Algeria (see “International transport activity”, below).

Compliance with market limits imposed by Italian sector-specific regulation, in terms of both volumes intake into the national network and sales volumes, will be assured through the optimal allocation of Eni’s gas availability from supply contracts and equity production between sales in Italy and in the rest of Europe, and the use of gas in Eni’s power generation plants, leveraging also on the expected increase in demand.

 

Gas in Italy
  2005   2006  
 
 
 
    (bcm)   Volumes sold   Market share (%)   Volumes sold   Market share (%)   Ch.% 2006 vs 2005  
                           
Italy to third parties       52.54   61.0   50.96   60.4   (3.0 )
Wholesalers       12.05   14.0   11.54   13.7   (4.2 )
Gas release       1.95       2.00       2.6  
Industries       13.07   15.2   13.33   15.8   2.0  
Power generation       17.6   20.4   16.67   19.8   (5.3 )
Residential       7.87   9.1   7.42   8.8   (5.7 )
Own consumption       5.54       6.13       10.6  
TOTAL SALES IN ITALY       58.08   67.4   57.09   67.6   (1.7 )
Gas demand       86.2       84.4          

 

MARKETING POLICY
Eni intends to implement a marketing policy more focused on value creation for its clients than in previous years, leveraging on its established know-how on pricing, personalization of services, and brand awareness. In future years, Eni’s marketing effort will be supported by developing an integrated offer of gas and electricity (“dual offer”), targeting mainly the middle and retail markets. The dual offer is expected to reap the benefits deriving from scale and integration, enabling in particular to achieve significant synergies from the integration of processes to acquire and manage clients.
  Eni will devote particular attention to developing the retail market where Eni is leader with 6.5 million of clients, located in the most important urban centers in Italy, served through different contact channels.
Broadly speaking, the commercial offer envisages:
  • for business clients, a dedicated commercial structure and a personalized commercial offer based on tailored contractual formulas and a panel of indexation options, as well as a spate of technical services addressing 7 areas (including cogeneration feasibility studies, check up of power facilities and gas regulation and measurement devices);

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  • for tertiary clients, public entities and civil buildings, in addition to various contractual formulas, Eni offers the so called “Servizio Energia” providing a turn-key solution for running, managing, upgrading and designing heating facilities;
  • for residential customers, a network of franchised outlets provides supply and installation of gas fired appliances, and planned and extraordinary maintenance of home heating facilities.

Dedicated to the different types of clients, Contact Centers provide information, consultancy and assistance on contracts and the administration and regulation aspects while supporting the commercial offer. The Internet site provides wider scope for interaction and represents a true on-line office where clients can perform all administrative functions and receive information on services and other relevant issues.
Eni intends to strengthen its competitive position in the retail market aiming at reinforcing costumer loyalty through value creation in terms of excellence of the service offered. New service formulas and the development of the dual offer will be key levers of the marketing effort. At the same time, Eni expects to preserve its selling margins by means of reducing the cost of services leveraging on the rationalization of its contact channels, streamlining administrative processes and exploiting economies of scale.

  DEVELOPMENT PROJECTS
Eni intends to strengthen its presence on the retail market through a strategy based on regional alliances with public and private partners. As part of this, Eni and its local municipal partners implemented the Toscana project, with the establishment of Toscana Energia Clienti by merging Eni’s selling activities and those of its local municipal partners. This new entity, controlled by Eni with a 79.22% interest, engages in selling natural gas on a regional base, boasting 600,000 clients and 1.1 bcm/y sales in 147 municipalities. This project also concerned distribution activities with the establishment of Toscana Energia SpA (Eni’s interest 48.72%) by merging Eni’s and its partners’ activities in gas distribution. This new entity is managed by Eni who deploys the role of industrial partner with relevant operating and management responsibilities.

1.2 Marketing in the rest of Europe
In 2006 gas sales in the rest of Europe were 34.81 bcm, up 4.90 bcm or approximately 16% from 2005.
Eni intends to strengthen its leadership in European gas markets, targeting sales volumes of approximately 53.3 bcm in 2010, equal to an average organic growth rate of 11% per year.

 

  Worldwide gas sales    (bcm)   2004   2005   2006
                 
Markets of the rest of Europe       26.84   29.91   34.81
Importers to Italy       10.96   11.53   14.10
Iberian Peninsula       3.59   4.59   5.24
Germany-Austria       3.96   4.23   4.72
Turkey       1.60   2.46   3.68
Hungary-Slovenia-Greece       3.46   3.53   3.26
North Europe       2.93   2.74   2.64
France       0.15   0.65   1.07
Other       0.19   0.18   0.10
Markets extra Europe       1.71   1.71   1.51
Upstream (1)       4.70   4.51   4.07
International gas sales       33.25   36.13   40.39
Italy       53.78   58.08   57.09
Worldwide gas sales       87.03   94.21   97.48
     
(1)   Does not include Eni’s share of sales made by Nigeria LNG (Eni’s share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006, respectively.

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A review of Eni’s presence in key European markets and commercial objectives at 2010 is presented below.    

France
Eni sells natural gas to industrial clients and wholesalers. Eni is pursuing an aggressive marketing policy to gain market share, in particular in the segment of small businesses which presents good profitability and development perspectives.
In the medium term, Eni expects to grow its current 1.1 bcm sales level at a 47% annual average growth rate, compared to an expected 3% average growth rate of market consumption, targeting volumes of approximately 5 bcm in 2010, equal to a 9% market share.

Germany
Eni is present on the German natural gas market through its affiliate GVS (Gasversorgung Süddeutschland GmbH - Eni 50%) which sold approximately 6.4 bcm in 2006, and with a direct commercial structure.
In the medium term, Eni plans to significantly increase its sales to the business segment, leveraging on the pursuit of new opportunities arising from the ongoing liberalization process. The objective is to sell more than 7.5 bcm in 2010, equal to a 7% market share.

IBERIAN PENINSULA
Gas demand growth in the Iberian Peninsula is expected to outpace average European growth.

Portugal
Eni operates on the Portuguese market through its affiliate Galp Energia (Eni’s interest 33.34%) which
  sold approximately 5 bcm in 2006 (1.65 bcm being Eni’s share).
In the medium term, Galp’s sales are expected to grow at an 8% average rate, targeting 6.3 bcm (2.1 Eni’s share) in 2010.

Spain
Eni operates in the Spanish gas market through Unión Fenosa Gas (Eni’s interest 50%) engaged in natural gas supply and sale to final users and to power generation utilities. In 2006 gas sales of Unión Fenosa Gas in Europe amounted to 4.34 bcm (2.17 bcm Eni’s share).
Unión Fenosa Gas is engaged in LNG through an 80% interest in the Damietta liquefaction plant, on the Egyptian coast (see below), and through a 7.36% interest in a liquefaction plant in Oman, completed in 2005; in addition, it holds interests in the Sagunto (Valencia) and El Ferrol (Galicia) regasification plants, with a 42.5% (21.25% Eni’s interest) and 18.9% interest (9.45% Eni’s interest), respectively.

Eni targets to increase its sales in the Iberian Peninsula from the current 5.2 bcm level to approximately 8.5 bcm by 2010 (13% average growth rate), mainly as a result of growing sales of Unión Fenosa Gas and the development of direct sales, in particular to the Spanish power generation segment, supplied mainly by means of LNG from Nigeria.

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UK/Northern Europe
Eni through North Sea Gas & Power unit of its subsidiary Eni UK Ltd sells equity gas produced at Eni’s fields in the North Sea and operates in the main continental natural gas hubs (NBP, Zeebrugge, TTF). Eni plans to grow volumes sold on the UK/North European markets from the current 2.64 bcm level to approximately 8 bcm by 2010, with a 32% average annual growth rate. In particular a significant increase is expected in spot sales on the Zeebrugge hub (from 0.2 bcm in 2006 to 4.2 bcm in 2010).
  In the UK, gas sales through North Sea Gas&Power are expected to grow from 2.5 bcm in 2006 to 3.8 bcm in 2010, equal to a 3% market share.

Turkey
Eni sells gas supplied from Russia and transported via the Blue Stream underwater pipeline. In 2006 sales amounted to 3.68 bcm. Leveraging on the expected demand growth, Eni plans to increase sales up to 6.4 bcm by 2010, equal to an 18% market share.

1.3 Supply
Eni enjoys a competitive advantage represented by its wide and diversified availability of natural gas both from equity production and from its unrivaled portfolio of long term purchase contracts with major producing countries, also boasting a direct upstream presence in 8 out of 10 gas supplying countries. Our diversified supply portfolio insulates us from the risk of being heavily dependent on a single source of supplies; in fact, none of Eni’s suppliers weighs for more than 25% of Eni current gas needs. In addition, the development of LNG projects will further strengthen the diversification of Eni’s supplies and their integration with upstream operations.
In 2006, Eni’s requirements for natural gas were met for over 92% with supplies from foreign countries (mainly Algeria, Russia, the Netherlands and Norway) and the remaining part was covered by equity gas.
  The strategic agreement with Gazprom, signed in November 2006, marks a fundamental step in enhancing security and flexibility of Eni’s gas supplies over the medium and long term. Based on this agreement, the duration of our long-term supply contracts increases from 14 to approximately 23 years and, when these contracts are fully operational in 2010, Eni will be able to purchase approximately 62.4 bcm/y (Russia 23.5, Algeria 21.5, the Netherlands 9.8, Norway 6, and Nigeria - LNG 1.6) to cope with rising demand according to our sales expansion plans in Europe. Furthermore, Eni can leverage on the flexibility of its contractual structure in order to capture market opportunities, also taking account of Eni’s availability of an integrated system for transport and logistics.

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An effective management of relationships with strategic countries supplying natural gas and the preservation of satisfactory long term relations continue to be priorities in running our gas business owing to the strategic clout of the security, diversification, and flexibility of supplies.


2. Infrastructure

Overview
Eni can access the widest network of infrastructure for transport and storage of natural gas in Europe which favored by its integration allows to link key consumption basins in Europe with the main producing areas (North Africa, Russia and the North Sea). In Italy Eni owns almost all the national gasline network and a relevant system of local distribution networks servicing retail markets.
The availability of regasification capacity in Italy and the Iberian Peninsula coupled with storage sites guarantees a high level of operating flexibility. These assets represent a significant competitive advantage.
With the aim of increasing diversification and safety of supplies and to cope with demand growth, Eni defined a massive plan for the upgrade of import infrastructure from Russia, Algeria and Libya, of regasification capacity and of national transport and distribution networks through capital expenditure of approximately euro 5.8 billion planned for the next four years.

2.1 International transport activities
Eni owns transportation rights in a network of international high pressure pipelines for a total of over 4,300 kilometers allowing the import to Italy of natural gas produced in Russia, Algeria, the North Sea and Libya, in particular:
  • the TAG PIPELINE, 1,140-kilometer long, made up of three lines, each about 380-kilometers long, with a transit capacity3 of 31 bcm/y, related to the build-up of the fourth import contract from Russia, and three compression stations, which transports natural gas from Russia across Austria from Baumgarten, the delivery point at the border of Austria and Slovakia, to Tarvisio, point of entry in the Italian natural gas transport system. This pipeline is going to be upgraded by 6.5 billion cubic meters/year starting in October 2008 with capital expenditure estimated at about euro 253 million (94% covered by Eni). The capacity of the first upgrade has been assigned to third parties importing natural gas into Italy in February 2006. Procedures have been defined for the assignment of the second upgrade;
 
  • the TTPC PIPELINE, 742-kilometer long, made up of two lines each 371-kilometers long with a transit capacity of 27 bcm/y and three compression stations, which transports natural gas from Algeria across Tunisia from Oued Saf Saf at the Algerian border to Cap Bon on the Mediterranean coast where it links with the TMPC pipeline. This pipeline is going to be upgraded by 6.5 billion cubic meters/year, of these 3.2 starting in April 2008 and 3.3 in October 2008 with capital expenditure estimated at euro 450 million. The capacity of the first upgrade has been assigned to third parties importing natural gas into Italy in 2006. The procedure for the assignation of the second upgrade has been completed in February 2007. The transit capacity of the downstream TMPC pipeline is already adequate to the upgrade of the TTPC;
  • the TMPC PIPELINE for the import of Algerian gas, 775-kilometer long, made up of five lines each 155-kilometer long with a transit capacity of 33.5 bcm/y which crosses underwater the Sicily Channel from Cap Bon to Mazara del Vallo in Sicily, the point of entry into the Italian natural gas transport system;
  • the TENP PIPELINE, 1,000-kilometer long (two 500-kilometer long lines) with transit capacity of 15.5 bcm/y and four compression stations, transports natural gas from the Netherlands through Germany, from the German-Dutch border of Bocholtz to Wallbach at the German-Swiss border;
  • the TRANSITGAS PIPELINE, 291-kilometer long, with one compression station, which transports natural gas from the Netherlands and from Norway crossing Switzerland with its 165-kilometer long main line and a 71-kilometer long doubling line, from Wallbach where it joins the TENP pipeline to Passo Gries at the Italian border. It has a transit capacity of 20 bcm/y.
    A new 55-kilometer long line from Rodersdorf at the French-Swiss border to Lostorf, an interconnection point with the line coming from Wallbach was built for the transport of Norwegian gas;
  • the GREENSTREAM PIPELINE for the import of Libyan gas with a transit capacity of 8 bcm/y which crosses underwater the Mediterranean Sea from Mellitah to Gela in Sicily, the point of entry into the Italian natural gas transport system. The pipeline started operations in October 2004 and in 2006 transported 7.7 bcm, of which (i) 6.6 bcm to Italian importers under long-term supply contracts targeting a full capacity of 8 bcm/y; (ii) 1.1 bcm of natural gas available from Libyan fields that could not be absorbed by the local market. An upgrade of the pipeline’s transport capacity from 8 to 11 bcm is being planned with an expenditure of euro 80 million to be achieved also with minor interventions for optimizing the transport system. This new capacity will be available from 2011 and will allow to monetize further volumes of natural gas reserves located in Libya through the sale on the Italian market.
     
(3)   Transit capacity is the maximum daily capacity entering in different access points of a trunkline and carried to the next trunkline.

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Eni holds a 50% interest in the Blue Stream underwater pipeline linking the Russian and Turkish coast of the Black Sea that started operations in 2002. Laid at a record depth of over 2,150 meters, this 774-kilometer long pipeline with two lines and a transmission capacity of 49 mmcm/d, will transport 16 bcm/y (Eni’s share 8 billion)   of Russian natural gas in 2010. The gasline includes a compression station at Dzhubga on the Russian coast of the Black Sea, made up of six turbocompressors and six measurement lines as well as an internally fired power plant.

 

Considering the planned upgrade of the TAG and TTPC pipelines, the current import capacity from Libya through the Greenstream pipeline (8 bcm/year), from 2009 a total of about 21 bcm/y   of new imports of natural gas will be available totally destined to third parties under non-discriminating procedures, in most cases already concluded (17.7 bcm sold on the market).

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2.2 Italian transport network
Eni, through Snam Rete Gas, a company listed on the Italian Stock Exchange, in which Eni holds a 50.04% interest, owns almost completely the Italian natural gas transport network as well as the only regasification terminal operating in Italy. Under Legislative Decree No. 164/2000 concerning the opening up of the natural gas market in Italy, transport activities are regulated by the Authority for Electricity and Gas which determines the methods for calculating tariffs and fixing the return on capital employed. This makes transport a low risk business capable of delivering stable performance in the long period.
Eni’s network extends for 30,889 kilometers and comprises:
(i) a national transport network extending over 8,497 kilometers, made up of high pressure trunklines mainly with a large diameter, which carry natural gas from the entry points to the system – import lines, storage sites and main Italian natural gas fields – to the linking points with the regional transport network. The national network includes also some interregional lines reaching important markets;
(ii) a regional transport network extending over 22,410 kilometers, made up of smaller lines and allowing the transport of natural gas to industries, power stations and local distribution companies of the various local areas served.

The major pipelines interconnected with import trunklines that are part of Eni’s national network are:

for natural gas imported from Algeria:
  • two lines with a 48/42-inch diameter, each approximately 1,500-kilometer long, including the smaller pipes that cross underwater the Messina Strait, which link Mazara del Vallo (on the Southern coast of Sicily) to Minerbio (near Bologna).
    This pipeline is undergoing an upgrade with the laying of a third line with a 48 inch diameter 328-kilometer long (of these 272 are already operating). Available transport capacity4 at the Mazara del Vallo entry point is approximately 86 mmcm/d;

for natural gas imported from Libya:

  • a 36-inch line, 67-kilometer long linking Gela, the entry point of the Greenstream underwater pipeline into the national network near Enna along the import pipeline from Algeria. Transport capacity at the Gela entry point is approximately 30 mmcm/d;
  for natural gas imported from Russia:
  • two lines with 42/36/34-inch diameters extending for a total length of approximately 900 kilometers that are linked to the Austrian network in Tarvisio and cross the Po Valley reaching Sergnano (near Cremona) and Minerbio. The pipeline is being upgraded by the laying of a third 264-kilometer long line with diameter from 48 to 56 inches; 232 kilometers already operating at the end of 2006, from Tarvisio to Zimella (Verona) and by the upgrading of the Malborghetto compression station. The pipeline transport capacity at the Tarvisio entry point amounts to approximately 101 mmcm/d plus the transport capacity available at the Gorizia entry point of approximately 5 mmcm/d;

     
(4)   Transport capacity is related to October 1, the first day of a thermal year.

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for natural gas imported from the Netherlands and Norway:
  • two lines, with a 48/34-inch diameter, 301-kilometer long extending from the Italian border at Passo Gries (Verbania), point of connection with the Swiss network, to the node of Mortara, in the Po Valley.
    The pipeline transport capacity at the Passo Gries entry point amounts to 63 mmcm/d;

for natural gas coming from the Panigaglia LNG terminal:

  • one line, with a 30-inch diameter, 170-kilometer long linking the Panigaglia terminal to the national network near Parma. The pipeline transport capacity at the Panigaglia entry point amounts to 13 mmcm/d.

In 2006, Eni’s national network of owned pipelines increased by 177 kilometers due to changes to existing lines (87 kilometers) and extensions of the regional network (90 kilometers).

Eni’s system is completed by: (i) 10 compressor stations with a total power of 758 MW; (ii) 5 marine terminals linking underwater pipelines with the on-land network at Mazara del Vallo, Messina and Gela in Sicily and Favazzina and Palmi in Calabria for the GreenStream pipeline.
The interconnections managed by Snam Rete Gas in the Italian transport network are guaranteed by 25 linkage and dispatching nodes and by 559 plant units including pressure reduction and regulation plants. These plants allow to regulate the flow of natural gas in the network and guarantee the connection of pipes working at different pressures.
For the next four years Eni approved a capital expenditure plan of approximately euro 4.2 billion aimed mainly at the upgrade of its transport network in view of the expected increase in import capacity (in particular from Russia and Algeria).

2.3 Regasification - LNG
Eni intends to strengthen its integrated LNG business on a global scale, aiming at further diversifying its supply sources, improving operational flexibility, and monetizing its large equity gas reserves. In particular, the development of regasification capacity is aimed at reinforcing and diversifying Eni natural gas supply portfolio.

  Eni’s main assets in LNG are:

Italy
Eni owns the only regasification terminal operating in Italy at Panigaglia (Liguria). At full capacity, this terminal can input 3.5 billion cubic meters/year into the Italian transport network. In 2006 a total of 3.12 bcm of natural gas were input in the national network, of these 52% were owned by Eni.
Eni plans to build a new regasification terminal located off the Adriatic coast (with a 50% interest) and to increase the capacity of the Panigaglia plant. These two projects are expected to upgrade the import capacity to Italy by 8 and 4.5 bcm/y, respectively, when fully operational. The planned start-up is expected by 2013 and 2014, respectively. The capital expenditure earmarked for the offshore regasification project amounts to approximately euro 800 million (of these euro 400 million for the 50% interest in the offshore regasification plant and euro 359 million for Panigaglia).

Egypt
Eni, through its interest in Unión Fenosa Gas, owns a 40% stake in the Damietta liquefaction plant producing approximately 5 mmtonnes/y of LNG equal to a feedstock of 7.6 bcm/y of natural gas. In June 2006, the partners of the project (Unión Fenosa Gas, the Spanish-Egyptian company SEGAS an affiliate of Unión Fenosa Gas, State owned Egyptian companies EGAS and EGPC, and oil producers Eni and BP) defined terms and conditions for doubling the plant capacity by means of another treatment train. Expected capital expenditure amounts to approximately $1.5 billion with start-up expected between 2010 and 2011. In order to market its share of natural gas, Eni intends also to build two gas tanker ships with a capacity of 155 kcm each.

Spain
In April 2006, the Sagunto regasification plant with a capacity of 6.7 bcm/y started operations near Valencia. Eni through Unión Fenosa Gas holds a 21.25% interest in this plant. At present, Eni’s share of regasification capacity amounts to 1.6 bcm/y of gas. A capacity upgrading plan has been sanctioned targeting a 0.8 bcm/y capacity increase by 2009. Relevant works started in the second half of 2006. Eni through Unión Fenosa Gas also holds a 9.5% interest in the El Ferrol regasification plant, located in Galicia, under construction and expected to be completed by the first half of 2007, targeting a treatment capacity of approximately 3.6 bcm/y, 0.4 bcm/y being Eni’s share.

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USA
Eni is entitled to a share of the initial planned capacity of the Cameron regasification terminal under construction in Louisiana, and expected to start operations in 2008-2009. The 6 bcm/y capacity represents approximately 40% of the initial capacity of the plant (15.5 bcm/y). This transaction will enable Eni to sell part of its gas reserves in the United States.
In order to support supplies to this plant, in February 2007 Eni signed an agreement with Nigeria LNG Ltd, operating the Bonny LNG plant in Nigeria, to purchase 1.375 mmtonnes/y of LNG, equivalent to 2 bcm/y of gas for a twenty-year period, gas deriving from the upgrade of the Bonny liquefaction plant (7 trains) expected for 2012. Eni also signed a memorandum of intent with Brass LNG for the purchase of 1.67 mmtonnes/y equivalent to 2.3 bcm/y, of LNG.

2.4 Distribution activities
Distribution involves the delivery of natural gas to residential and commercial consumers in urban centers through low pressure networks. Eni, through its 100% subsidiary Italgas and other subsidiaries, is engaged in the distribution activity in Italy serving 1,317
  municipalities through a low pressure network consisting of approximately 49,000 kilometers of pipelines supplying 5.6 million customers.
Under Legislative Decree No. 164/2000 concerning the opening up of the natural gas market in Italy, distribution activities are regulated by the Authority for Electricity and Gas which determines the methods for calculating tariffs and fixing the return on capital employed. This makes distribution a low risk business capable of delivering stable performance in the long period. The management of networks is entrusted to natural gas companies by local Authorities exclusively under bid procedures. Concessions existing at the coming into force of Legislative Decree No. 164/2000 and awarded with a bid procedure expire on December 31, 2012; all other concession expire on December 31, 2007 (with an optional three-year extension under certain conditions).
Eni intends to optimize its concession portfolio maintaining its current size in terms of end users served by focusing on development initiatives in core areas and promoting local alliances aimed at supporting sale activities on retail markets.

 

  Distribution Italy        2004   2005   2006
                 
Volumes distributed   (bcm)   8.14   8.65   7.54
to Eni       7.73   8.13   6.90
to third parties       0.41   0.52   0.64
Installed network   (km)   46,954   48,146   48,724
Active meters   (no. of users)   5,418,262   5,838,085   5,550,700
Municipalities served       1,227   1,282   1,317

 

For the next four years Eni defined a capital expenditure plan of approximately euro 0.8 billion for the   development and maintenance of distribution networks and for the purchase of interests in distribution networks.

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Contents

ENI FACT BOOK / GAS & POWER - ACTIVITIES

3. Power Generation

Eni engages in power generation activities in its power stations at Ferrera Erbognone, Ravenna, Livorno, Taranto, Mantova, Brindisi and Ferrara. In 2006, electricity production sold was 24.82 TWh, up 2.05 TWh or 9% as compared to 2005. Increased production reflected the ramp-up of the Brindisi plant. Total installed capacity was 4.9 GW at December 31, 2006.
By 2010 Eni intends to complete its plan for expanding power generation capacity, targeted at an installed capacity of 5.5 GW fully operational in 2010 with production amounting to 31 TWh, corresponding to approximately 8% of electricity generated in Italy at that date. When fully operational, natural gas volumes
  supplied will amount to 6 bcm/y from Eni’s diversified supply portfolio. Planned capital expenditure amounts to approximately euro 2.4 billion, of these works for euro 2 billion have already been completed.
The development plan is underway at Ferrara (Eni’s interest 51%), where in partnership with EGL Luxembourg (a company belonging to Swiss group EGL) construction of two new 390 MW combined cycle units is underway. This will bring installed capacity to 840 MW (two CGT for a total of 780 MW in addition to the existing 60 MW units) with start-up expected in 2007. Eni has also planned the installation of a new 240 megawatt combined cycle unit located in Taranto (current capacity 75 megawatt).

New installed generation capacity uses the combined cycle gas fired technology (CCGT), ensuring a high level of efficiency and low environmental impact.
In particular, management estimates that for a given amount of energy (electricity and heat) produced, the use of the CCGT technology on a production of 30 TWh reduces emissions of carbon dioxide by approximately 11 mmtonnes, as compared to emissions using conventional power generation technology5.
  Restructuring of power generation activities and dual offer
In 2006 the G&P division launched a restructuring plan of its power generation activities, which provides for the transfer of electricity marketing activities from EniPower, the company that had managed them since its establishment, to the division starting in 2007.
This will allow an integrated management of Eni’s gas-electricity portfolio and to develop a combined electricity/gas offer to customers. Power generation activities will remain at EniPower.

 

     
(5)   Eni power plants in operation and under construction employ the combined cycle technology, the most efficient technology currently available for power generation, with 12% higher efficiency than the most upstead coal-fired plants and lower polluting emissions per kWh produced.

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Contents

ENI FACT BOOK / GAS & POWER - MAIN DATA

  Supply of natural gas  

(bcm)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                                             
Italy   16.81     17.70     16.16     13.64     14.62     12.67     12.16     11.30     10.73     10.21  
Russia for Italy   13.75     16.69     19.09     21.03     19.51     18.62     18.92     20.62     21.03     21.30  
Russia for Turkey                                       0.63     1.60     2.47     3.68  
Algeria   16.02     16.83     20.40     21.56     18.39     16.35     16.53     18.86     19.58     18.84  
Netherlands   5.00     3.02     2.87     6.09     7.00     7.55     7.41     8.45     8.29     10.28  
Norway                           1.10     4.83     5.44     5.74     5.78     5.92  
Hungary   2.79     2.73     2.67     2.67     3.11     3.05     3.56     3.57     3.63     3.28  
United Kingdom                                 1.48     1.98     1.76     2.28     2.50  
Libya                                             0.55     3.84     6.63  
Croatia                                 0.31     0.65     0.35     0.43     0.86  
Algeria (LNG)   1.89     1.99     2.06     2.01     1.79     1.92     1.98     1.27     1.45     1.58  
Others (LNG)                                 0.30     0.72     0.70     0.69     1.57  
Other supplies Europe   0.01     0.01     0.01     0.02     0.03     0.03     0.04     0.12     1.18     1.85  
Outside Europe                     0.94     0.96     0.96     1.14     1.20     1.18     0.77  
Outside Italy   39.46     41.27     47.10     54.32     51.89     55.40     59.00     64.79     71.83     79.06  
Total supply   56.27     58.97     63.26     67.96     66.51     68.07     71.16     76.09     82.56     89.27  
Offtake from (input to) storage                     (2.43 )   0.13     (1.43 )   0.84     0.93     0.84     (3.01 )
Network losses and measurement differences   (0.33 )   (0.56 )   (0.34 )   (0.90 )   (0.92 )   (0.50 )   (0.61 )   (0.53 )   (0.78 )   (0.50 )
Available for sale of Eni’s own companies   55.94     58.41     62.92     64.63     65.72     66.14     71.39     76.49     82.62     85.76  
Available for sale of Eni’s affiliates   0.13     0.16     0.16     0.87     1.38     2.40     6.94     5.84     7.08     7.65  
Total available for sale G&P   56.07     58.57     63.08     65.50     67.10     68.54     78.33     82.33     89.70     93.41  

 

  Gas sales  

(bcm)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                                             
Italy   53.10     55.62     60.19     57.82     56.74     50.43     50.86     50.08     52.47     50.94  
Wholesalers (selling companies)   19.97     21.59     22.68     20.68     21.09     17.02     15.36     13.87     12.05     11.54  
Gas release                                             0.54     1.95     2.00  
     End customers   33.13     34.03     37.51     37.14     35.65     33.41     35.50     35.67     38.47     37.40  
     Industries   17.02     17.11     17.84     18.37     18.53     14.43     13.17     12.39     13.07     13.33  
     Power generation   10.14     10.47     13.01     12.27     12.21     12.48     15.03     15.92     17.60     16.67  
     Residential   5.97     6.45     6.66     6.50     4.91     6.50     7.30     7.36     7.80     7.40  
Rest of Europe   2.84     2.79     2.73     3.90     6.05     12.77     17.54     21.54     23.44     27.93  
Outside Europe                     0.91     0.93     0.92     1.09     1.17     1.17     0.76  
Total sales to third parties   55.94     58.41     62.92     62.63     63.72     64.12     69.49     72.79     77.08     79.63  
Own consumption                     2.00     2.00     2.02     1.90     3.70     5.54     6.13  
Total sales to third parties and own consumption   55.94     58.41     62.92     64.63     65.72     66.14     71.39     76.49     82.62     85.76  
Sales of natural gas of Eni’s affiliates (net to Eni)   0.13     0.16     0.16     0.87     1.38     2.40     6.94     5.84     7.08     7.65  
Italy                                                   0.07     0.02  
Rest of Europe                     0.41     0.93     1.93     6.23     5.30     6.47     6.88  
Outside Europe   0.13     0.16     0.16     0.46     0.45     0.47     0.71     0.54     0.54     0.75  
Total sales and own consumption G&P   56.07     58.57     63.08     65.50     67.10     68.54     78.33     82.33     89.70     93.41  

 

  Gas volumes transported
in Italy
(1)
 

(bcm)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                                             
Eni   53.14     55.69     59.67     63.73     58.17     54.56     51.74     52.15     54.88     57.09  
On behalf of third parties   4.35     6.07     6.90     9.45     11.41     19.11     24.63     28.26     30.22     30.90  
     Enel   2.48     4.04     4.50     6.27     6.28     8.28     9.18     9.25     9.90     9.67  
     Edison Gas         1.27     1.52     2.10     2.98     4.61     7.49     8.00     7.78     8.80  
     Others   1.87     0.76     0.88     1.08     2.15     6.22     7.96     11.01     12.54     12.43  
    57.49     61.76     66.57     73.18     69.58     74.40     76.37     80.41     85.10     87.99  
     
(1)   Include amounts destined to domestic storage.

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Contents

ENI FACT BOOK / GAS & POWER - MAIN DATA

  Transport infrastructure
Route  

Length of main line
(km)

 

Lines
(units)

 

Diameter
(inch)

 

Pressure min-max
(bar)

 

Transport capacity
(mmcm/d)

 

Transit capacity
(mmcm/d)

 

Compression stations
(units)

Italy                            
Mazara del Vallo-Minerbio (under upgrading)  

1,540

 

2/3

 

48/42

 

75

 

87.0

     

7

Tarvisio-Sergnano-Minerbio (under upgrading)  

445

 

2/3

 

56/48/42/36/34

 

58/70

 

84.4

     

2

Passo Gries-Mortara  

177

 

2

 

48/34

 

54/75

 

57.5

     

1

Outside Italy (1) (2)                            
TENP (Bocholtz-Wallbach)  

500

 

2

 

36/38/40

     

69.6

 

47.3

 

4

Transitgas (Rodersdorf-Lostorf)  

165

 

1+1 71 km
+ one 55 km

 

36/48

     

76

 

61.0

 

1

TAG (Baumgarten-Tarvisio) (under upgrading) (3)  

380

 

3

 

36/38/40/42

     

101.3

 

93.5

 

3

TTPC (Oued Saf Saf-Cap Bon)  

371

 

2

 

48

     

82.3

 

81.2

 

3

TMPC (Cap Bon-Mazara del Vallo)  

155

 

5

 

20/26

     

100.5

 

100.5

   
Greenstream (Mellitah-Gela) (4)  

520

 

1

 

32

     

24.4

 

24.4

 

1

Blue Stream (Beregovaya-Samsun) (4)  

391

 

1+1 383 km

 

24

     

49.0

 

49.0

 

1

     
(1)   As of December 31, 2006.
(2)   Capacity is related to standard conditions: pressure 1.01325 bar; temperature 288.15 K.
(3)   As of January 1, 2007.
(4)   Data relate to full operation of the transport system.

Transport capacity includes both transit capacity and maximum daily volumes of natural gas destined to local markets and withdrawn at various points along the pipeline.
Transit capacity is the maximum daily volume of natural gas which is input at various entry points along the pipeline and transported to the next pipeline.

 

  EniPower power stations
Power stations  

Installed
capacity at 2005

(GW)

 

Installed
capacity at 2006

(GW)

 

Full installed
capacity (2010)
(GW)

 

Effective/
planned
start-up

 

Fuel

Brindisi  

1.3

 

1.5

 

1.3

 

2006

 

gas

Ferrera Erbognone  

1.0

 

1.0

 

1.0

 

2004

 

gas/syngas

Livorno  

0.2

 

0.2

 

0.2

 

2000

 

gas

Mantova  

0.8

 

0.9

 

0.8

 

2005

 

gas

Ravenna  

1.0

 

1.1

 

1.0

 

2004

 

gas

Taranto  

0.1

 

0.1

 

0.4

 

2000-2009

 

gas

Ferrara  

0.1

 

0.1

 

0.8

 

2007

 

gas

   

4.5

 

4.9

 

5.5

       

Full installed capacity net of standstill of obsolete plants.

 

   Power generation         

2000

   

2001

   

2002

    

2003

    

2004

   

2005

   

2006

                                 
Purchases                                
Natural gas  

(mmcm)

 

827

 

784

 

819

 

940

 

2,617

 

4,384

  4,775
Other fuels  

(ktoe)

 

842

 

936

 

885

 

847

 

695

 

563

  616
- of which cracking steam                      

89

 

96

 

136

Sales                                
Electricity production sold  

(TWh)

 

4.77

 

4.99

 

5.00

 

5.55

 

13.85

 

22.77

  24.82
Electricity trading  

(TWh)

     

1.56

 

1.74

 

3.10

 

3.10

 

4.79

  6.21
Steam production sold  

(ktonnes)

 

9,535

 

10,025

 

9,302

 

9,303

 

10,040

 

10,660

  10.287
Installed generation capacity  

(GW)

 

1.0

 

1.0

 

1.0

 

1.9

 

3.3

 

4.5

  4.9

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Contents

ENI FACT BOOK / REFINING & MARKETING

                 
  Key performance indicators  

2004

 

2005

 

2006

 
  Net sales from operations (a)   (million euro)  

26,089

 

33,732

 

38,210

 
  Operating profit      

1,080

 

1,857

 

319

 
  Adjusted operating profit      

923

 

1,214

 

790

 
  Adjusted net profit      

674

 

945

 

629

 
  Capital expenditure      

693

 

656

 

645

 
  Adjusted capital employed, net      

4,835

 

5,326

 

5,766

 
  ROACE adjusted   (%)  

13.0

 

18.2

 

10.7

 
  Refining throughputs on own account   (mmtonnes)  

37.69

 

38.79

 

38.04

 
  Refining throughputs of wholly-owned refineries      

26.75

 

27.34

 

27.17

 
  Balanced capacity of wholly-owned refineries   (kbbl/d)  

524

 

524

 

534

 
  Balanced capacity utilization rate   (%)  

100

 

100

 

100

 
  Retail sales of petroleum products on Agip branded network in Europe   (mmtonnes)  

12.35

 

12.42

 

12.48

 
  Agip branded service stations in Europe at period end   (units)  

6,225

 

6,282

 

6,294

 
  Average throughput of Agip branded service stations in Europe   (kliters)  

2,488

 

2,479

 

2,470

 
  Employees at year end   (units)  

9,224

 

8,894

 

9,437

 
       
  (a)   Before elimination of intersegment sales.

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Contents

ENI FACT BOOK / REFINING & MARKETING - STRATEGIES

STRATEGIES
Eni is leader in the refining business and in the marketing of refined products in Italy and holds solid competitive positions in selected European countries. Eni’s refining and marketing operations are efficiently integrated to maximize cost efficiencies and deliver appreciable returns on capital employed. The integration with upstream operations represents a further competitive advantage. Eni’s key medium term objective in its downstream oil business is to enhance profitability. The strategic guidelines to attain this objective are the following:

In the next four years the implementation of these strategies will be supported by a capital expenditure program of approximately euro 4.3 billion, focused on upgrading refineries, through an increase of primary balanced refining and conversion capacity and of refineries’ flexibility and efficiency, with the objective to strengthen Eni’s role of leading player in the Mediterranean area, targeting a leadership position in Europe, and enhancing Eni’s competitive position in marketing in Italy and in selected European markets.

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Contents

ENI FACT BOOK / REFINING & MARKETING - HIGHLIGHTS

2006 Highlights

In 2006, adjusted net profit was down euro 316 million to euro 629 million, or 33.4%, mainly due to a decline in refining margins as a result of a weak trading environment and to lower results from marketing in Italy.

Eni’s realized refining margins recorded a better trend than market reference margins reflecting Eni’s refineries capacity to process heavy crudes which are discounted as compared to the Brent crude market benchmark, thus resulting in a higher profitability of the heavy barrel.

Return on average capital employed adjusted was 10.7%, down from 2005 (18.2%).

Capital expenditure totaled euro 645 million and mainly related to projects aimed at improving flexibility and yields of refineries and upgrading the retail network in Italy and in the rest of Europe.

Refining throughputs on own account in Italy and outside Italy (38.04 mmtonnes) declined by 750 ktonnes from 2005, down 1.9%, mainly owing to longer unplanned maintenance standstills, particularly at third party refineries (Priolo), while wholly-owned refineries achieved stable processing levels.

Total refinery intake amounted to 39.56 mmtonnes, of which 35 in Italy, with full balanced capacity utilization.
  Retail sales of refined products in Italy (8.66 mmtonnes) declined 1% from 2005 mainly due to competitive pressure. This decrease was more than offset by a growth in retail volumes marketed in the rest of Europe (3.82 mmtonnes, up 4.1%), mainly in Germany and Spain.

Sales on the wholesale market in Italy (10.06 mmtonnes) were down 4% due primarily to a decline registered in the fourth quarter owing to the impact of mild weather conditions. This decline was partially offset by a growth in volumes marketed on wholesale markets in the rest of Europe (4.6 mmtonnes, up 2.2%) in particular in Germany and Spain.

 

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Contents

ENI FACT BOOK / REFINING & MARKETING - ACTIVITIES

Activities

1. Refining

Eni owns five refineries in Italy and interests in refineries located in Italy, Germany and the Czech Republic with a total refining capacity (balanced with conversion capacity) of approximately 35.5 million tonnes (equal to 710 kbbl/d) and a conversion index of 57%. Eni’s wholly owned refineries in Italy have a balanced capacity of 26.7 mmtonnes (equal to 534 kbbl/d), with a 58.9% conversion rate.
In 2006 refining throughputs on own account in Italy and outside Italy were 38.04 mmtonnes; total throughputs on wholly owned refineries were 27.17 mmtonnes (on own account and for third parties), with full balanced capacity utilization.
In the medium term, Eni forecasts the refining environment to be featured by the following trends: (i) global imbalances in the availability of products among macro geographic areas; (ii) a low adequacy of existing refining assets to process heavy and non conventional feedstock against a backdrop of persisting high spreads between light/sweet and heavy/sour crude qualities; (iii) an imbalance of existing refining assets towards higher yields in gasoline and fuel oil in contrast with rising demand for middle distillates;
  and (iv) increasingly tight environmental and product quality regulations which make the upgrading of existing refining assets a critical issues. Against this backdrop, Eni plans to enhance the profitability of its refining business, capturing opportunities arising from current market trends by implementing a large investment program of approximately euro 3 billion in the next four years. Principal planned actions are to: (i) increase primary and conversion capacity, targeting a complexity index higher than 57%, in view of boosting middle distillate yields, including petrochemical feedstock, and extracting value from equity crude, the availability of which is expected to increase in the Mediterranean basin over the medium term; (ii) improve refinery flexibility in order to optimize processed feedstock and capture market opportunities arising from an expected increasing availability of heavy/sour crude which can be purchased at a discount in the marketplace; (iii) achieve high-quality products responsive to expected demand trends and the evolution of product specifications provided for by increasingly tight European standards in term of emissions and environmental preservation; (iv) strengthen vertical integration with upstream and petrochemical operations; and (v) enhance operational efficiency of refineries, targeting in particular a higher level of energy efficiency.

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Contents

ENI FACT BOOK / REFINING & MARKETING - ACTIVITIES

ITALY
Eni’s refining system in Italy is composed of five wholly owned refineries and a 50% interest in the Milazzo refinery in Sicily. Each of Eni’s refineries in Italy has operating and strategic features that aim at maximizing the value associated to the asset structure, the geographic positioning with respect to markets and the integration with Eni’s other activities.

SANNAZZARO: with a balanced primary refining capacity of 170 kbbl/d and an equivalent conversion index of 46.2% is one of the most efficient refineries in Europe. Located in the Po Valley, it supplies mainly markets in North-Western Italy and Switzerland. The high degree of flexibility of this refinery allows it to process a wide range of oils, such as CPC Blend crude oil from the Caspian Sea carried through the CPC pipeline, the Bonga crude from Nigeria and oil from Eni’s Villafortuna field. From a logistical standpoint this refinery is located along the route of the Central Europe Pipeline, which links the Genova terminal with French speaking Switzerland.
  This refinery contains two primary distillation plants and a vacuum unit. Conversion is obtained through a fluid catalytic cracker (FCC1), an HDCK middle distillate conversion unit and a visbreaking thermal conversion unit. Two catalytic reforming plants, an isomerization plant, an alkylation plant, an MTBE plant and three desulphurization plants for middle distillates and one for naphtha from cracking complete the production cycle. In 2006, Eni completed a gasification facility using the heavy residue from visbreaking (tar) to produce syngas to feed the nearby EniPower power station at Ferrera Erbognone.

Eni plans to upgrade this refinery, targeting to transform it into a world class plant. In particular,
in the next four years, Eni plans to build:
  • a high pressure hydrocracking unit with a capacity of 28 kbbl/d, able to produce over 1 mmtonnes/y of high quality middle distillates, in particular diesel fuel with low sulphur content and kerosene.
    Start-up is planned at 2008 end;

     
(1)   Conversion plant where vacuum feedstock undergoes cracking at high pressure and moderate temperature thus producing mostly high quality gasoline. This kind of plant guarantees high operating flexibility to the refinery.

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Contents

ENI FACT BOOK / REFINING & MARKETING - ACTIVITIES

  • a PDA deasphalting unit with a 28 kbbl/d capacity for the production of deasphalted oil (without asphaltene and metals) from visbreaking and vacuum unit residues to be used as feedstock for the FCC unit. Further residues will be used as feedstock for the tar gasification plant. The deasphalting plant will enable Eni to increase the refinery’s flexibility thanks to the processing of a higher amount of high sulphur content crude, thus increasing the yield of valuable products (diesel fuel). Start-up is planned in 2008.

Eni is currently evaluating the building of a plant employing Eni Slurry Technology (see “Innovative technologies”, below) with a 23 kbbl/d capacity for the processing of extra heavy crudes and tar sands producing higher quality products, in particular diesel fuel, and reducing the yield of fuel oil to zero.

TARANTO: with a balanced primary refining capacity of 110 kbbl/d and an equivalent conversion index of 61.1%, can process a wide range of crudes and semi-finished products with great operational flexibility. It mainly produces fuels for automotive use and residential heating purposes for the southern Italian markets. Besides its primary distillation plants, this refinery contains a flash vacuum unit, two plants for the desulphurization of middle distillates, a reforming unit, an isomerization unit and conversion plants such as: a two-stage thermal conversion plant (visbreaking/thermal cracking) and an RHU conversion plant, that allows to convert high sulphur content residues into valuable products and cracking feedstocks. It processes most of the oil produced in Eni’s Val d’Agri fields carried to Taranto through the Monte Alpi pipeline (in 2006 a total of 3.157 mmtonnes of this oil were processed).
Eni plans to develop and upgrade this refinery, targeting to transform it into a world class one. In particular, two projects are planned: (i) the building of a new high pressure hydrocracking unit with a 17 kbbl/d capacity and the revamping of the hydrogen production unit; these assets will allow to produce approximately 0.6 mmtonnes/y of high quality gasoil, when fully operational. Start-up is planned in 2008; (ii) the building of a new topping2 unit with a 4 mmtonnes/y capacity and an associated vacuum unit with a 2.5 mmtonnes/y capacity. Eni also plans to build a new unit for the desulphurization of middle distillates with a 2.3 mmtonnes/y capacity, in addition to utilities and logistic facilities

  (see “Logistics”, below), in particular a pipeline for transporting virgin naphtha to Eni petrochemical plant at Brindisi. The objective is to expand the consumption area covered by the refinery to Campania. Start-up is expected in 2009/2010.
This development and upgrading plan will enable Eni to better employ national and Caspian equity crude and give more flexibility to this refinery, optimizing the use of the conversion plants and increasing throughput from 6 to 10 mmtonnes/y (100-180 kbbl/d).

GELA: with a balanced primary refining capacity of 100 kbbl/d and an equivalent conversion index of 143.5% represents an upstream integrated pole with the production of heavy crudes obtained from nearby Eni fields offshore and onshore Sicily, while downstream it is integrated with Eni’s nearby petrochemical plants. Located on the southern coast of Sicily, it manufactures fuels for automotive use and residential heating purposes, as well as petrochemical feedstocks.
Its high conversion level allows it to minimize the yield of fuel oil and semi-finished products.
Besides its primary distillation plants, this refinery contains the following plants: an FCC unit with go-finer for the upgrading of feedstocks and two coking plants for the vacuum conversion of heavy residues. All these plants are integrated in order to process heavy residues and feedstocks and manufacture valuable products. It also contains two reforming units, an alkilation unit, an MTBE unit and plants for desulphurization of gasoil and naphtha from cracking. The power plant of this refinery also contains modern residue and exhaust fume treatment plants which allow the complex to comply with the most exacting environmental standards.
An upgrade of the Gela refinery will be implemented by means of an upgrade of topping capacity to enable higher intakes (approximately 1 mmtonnes/y) and of feedstock flexibility. In addition, actions to improve energy efficiency, renewal of facilities for gasoline production, and the upgrade of utilities and the logistic reorganization of the site are planned.

LIVORNO: with a balanced primary refining capacity of 84 kbbl/d and an equivalent conversion index of 11.4%, manufactures mainly gasolines, fuel oil for bunkering, specialty products and lubricant bases.
     
(2)   Topping (also called atmospheric distillation) represents the first stage of primary distillation of crude aimed at separating products thanks to the different boiling temperatures of the hydrocarbons contained in crude.

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Besides its primary distillation plants, this refinery contains a vacuum unit, a reformer unit, an isomerization plant, two desulphurization units for middle distillates and two lubricant manufacturing lines. Its pipeline links with the local harbor and with the Florence storage sites by means of two pipelines optimizing intake, handling and distribution of products.

PORTO MARGHERA: with a balanced primary refining capacity of 70 kbbl/d and an equivalent conversion index of 22.8%, supplies mainly markets in north-eastern Italy, Austria, Slovenia and, at a lower extent, Croatia. Besides its primary distillation plants with vacuum plants, this refinery contains a reformer plant, an isomerization plant, two gasoil desulphurization units and a two-stage thermal conversion plant (visbreaking/thermal cracking) for increasing yields of valuable products.
The plant upgrading project, subject to the extension of the refining license, concerns the construction of a new hydrocracker with a 24 kbbl/d capacity and upgrades of utilities. The objective is to increase intake (up 1.4 mmtonnes/y, to approximately 5.5 mmtonnes when fully operational), the improvement of flexibility in processed feedstocks, the increase in middle distillates produced (up 0.7 mmtonnes) in an area characterized by structural diesel fuel deficit, and higher energy efficiency.

REST OF EUROPE
In Germany Eni holds an 8.3% interest in the SCHWEDT refinery and a 20% interest in BAYERNOIL, an integrated pole that includes the Ingolstadt, Vohburg and Neustadt refineries. Eni’s refining capacity in Germany amounts to approximately 70 kbbl/d. Eni’s share of the production of the three integrated refineries and of the Schwedt refinery is mainly used to supply Eni’s distribution network in Bavaria and Eastern Germany. Eni plans to restructure the Bayernoil refining pole, by building a new hydrocracker with a capacity of approximately 2 mmtonnes/y, revamping other assets (in particular a reformer and a hydrofiner) and shutting-down a topping unit.
Eni holds a 16.33% interest in CESKA RAFINERSKA which owns and manages two refineries, Kralupy and Litvinov, in the Czech Republic. Eni’s share of refining capacity amounts to 27 kbbl/d.

2. Logistics

Eni is leader in storage and transport of petroleum products in Italy with its logistical integrated
  infrastructure consisting of 12 directly managed storage sites and a network of petroleum product pipelines.
Eni holds interests in five joint entities established by partnering the major Italian operators. These are located in Vado Ligure-Genova (Petrolig), Arquata Scrivia (Sigemi), Venice (Petroven), Ravenna (Petra) and Trieste (DCT) and aim at reducing logistic costs, and increasing efficiency.
Eni operates in the transport of oil and refined products: (i) on land through a pipeline network of leased and owned pipelines extending over 3,210 kilometers (1,513 kilometers are wholly owned by Eni); (ii) by sea through spot and long-term lease contracts of tanker ships. For the distribution of refined products to retail and wholesale markets, Eni owns a fleet of tanker trucks and manages third-party owned vehicles.
In the medium-term, Eni plans to enhance the relationship between its logistic and refining operations by implementing an integrated logistic model (“hub” model) designed to centralize handling of products flows on a single platform enabling real time monitoring.
In the next four years, Eni plans to invest approximately euro 0.6 billion directed in particular to the implementation of the Taranto logistic project intended to support the refinery’s development plan: a new diesel fuel and gasoline storage site will be built in Campania and three pipelines will be laid, two of which linking the refinery to the storage site and the other one to transport virgin naphtha to Eni’s petrochemical complex in Brindisi. The objective of this plan is to eliminate the transport of refined products by sea to Naples.

3. Marketing

RETAIL SALES
In retail distribution Eni intends to enhance its leadership on the Italian retail market, improving outlets and service quality standards and targeting a strong product differentiation and customer-oriented promotional initiatives.
In the rest of Europe, Eni will selectively grow its market share, targeting a strengthening of its competitive positioning in selected markets, leveraging on synergies achievable thanks to the geographic location of its production and logistic assets and on strong brand awareness.

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ITALY
Eni is leader in the retail marketing of refined product under its Agip brand.
At December 31, 2006, Eni’s retail distribution network consisted of 4,356 Agip branded service stations with sales amounting approximately to 11 billion liters (8.66 mmtonnes) with an average throughput of 2.46 mml and a 29.3% market share.

Eni intends to strengthen its competitive positioning in Italy by introducing new outlet formats in line with European standards of quality and services, increasing premium products sales and differentiating promotional offers in order to retain the various segments of clients.
A strong focus will be devoted to pursue high levels of operating efficiency.
In the next four years, Eni plans to invest approximately euro 0.75 billion in the upgrading of its network, targeting to build and acquire new service stations, highgrade/restructure existing ones, and to adequate them to applicable environmental standards and regulations.
By 2010, Eni expects to have a retail network
  composed of approximately 4,360 service stations with an average throughput of approximately 2.7 bl per outlet.

As for “premium price” products, Eni intends to enhance its “Blu fuel” line of products by launching a new diesel fuel with high environmental quality and engine performance.
In 2006, sales of BluDiesel – a high performance virtually sulphur free diesel fuel that improves engine performance – on the Agip branded network amounted to approximately 840 bl (760 mmtonnes), a decline of 14.8% from 2005 due mainly to the increasingly high sensitivity of consumers to the price of fuels in light of their remarkable increase in the year. At 2006 year-end, service stations marketing BluDiesel were 4,061 (about 4,000 at 2005 year-end) corresponding to approximately 93% of Eni’s Agip branded network.
Retail volumes of BluSuper – a high performance and low environmental impact gasoline – amounted to about 114 mml (98 ktonnes), down 9% from 2005,

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showing a trend similar to the one of BluDiesel. At 2006 year-end, service stations marketing BluSuper were 2,316 (about 1,719 at December 31, 2005) corresponding to approximately 53% of Eni’s network.

In January 2006 Eni started the experimental marketing of Ad-Blue®, a water solution containing urea for technologically advanced heavy duty vehicles.
This additive, compatible with the new characteristics of most trucks built in Europe, reacts with exhaust gases reducing emissions and consumption and improving engine performance.
In 2006 Eni continued its Do-It-Yourself campaign which enables customers accessing self-service outlets with an electronic card to obtain price discounts or gifts (under agreements with Vodafone and Coop) in proportion to the total amount of purchased fuel. Further bonuses are offered to the most faithful customers. At year-end the number of active cards was about 3.9 million; turnover on cards increased by 3% from 2005. The amount of fuel purchased with cards was approximately 39% of all fuels marketed on Agip branded service stations joining the campaign, corresponding to about 31% of total Agip throughput.

You&Agip
In March 2007, Eni launched its You&Agip promotional campaign designed to boost customer loyalty to the Agip brand. It is an innovative formula intended to outperform traditional loyalty programmes for motorists, mainly by cancelling the usual time limits, as it is set to last for the next three years until December 31, 2009. Furthermore, the list of prizes will be kept constantly updated thanks to the high numbers of partners joining the initiative. Just to mention a few qualifying features of the You&Agip programme, customers can decide how to accumulate points, when to spend them and what kind of reward to choose. Points can be accumulated not only by buying fuels, but also by buying all the other services and wares sold at AgipCafè outlets.
In 2006, Eni continued the initiative of the European Multicard Routex paying card addressed to professional transport (transporters and car fleets) with sales of 1.5 bl (up 4.7% from 2005), and the number of customers provided with this card increased by about 2,000 to 52,000 users at year end. Multicard is used internationally and is part of the international Routex consortium, made up by Agip, Aral, BP, OMV and Statoil.
Eni continued the development of its non oil-retail activities aimed at promoting the development of its network in line with European standards, such as the diffusion of self-service facilities, high-tech car care systems and services to customers, in particular 1,000 cafè
  and fast food outlets as well as innovative commercial outlets. To this end Eni owns master franchisor rights with exclusive rights for the oil sector for the “Pans & Co” brand, a leader in quality fast food outlets. Eni’s network contains 13 Pans & Co outlets and 32 McDonald’s outlets both on ordinary and motorway assets.
In 2006, a total of 70 new affiliations were added to the AgipCafè® branded outlets and by year end a total of 340 franchises. Moreover, 9 new convenience stores under the “SpazioAgip®” brand name were opened, thus reaching a total of 23 locations. Also 45 new car-wash facilities were opened on Agip owned service stations, thus reaching a total of 715 units. In particular the travellers who stop at Agip branded stations along the motorways can access a wide range of services: AgipCafè, l’Angolo del Buongustaio, SpazioAgip, RistorAgip, BabyRoom and special rest areas dedicated to motor homes.
Eni has also developed the AgipTruck Point, large-format specialized service stations for heavy duty vehicles where facilities have been created for truck drivers such as secure parking and IT services.
In the next four years Eni intends to continue the development of its non-oil activities and expects to provide 57% of its Agip branded network with these facilities by 2010 (53% in 2006).

REST OF EUROPE
In 2006, retail volumes of fuels marketed in the rest of Europe totalled 4.8 bl (3.82 mmtonnes).
At December 31, 2006, Eni’s retail marketing network outside Italy was represented by 1,938 service stations with an average throughput of 2.5 mml.
The areas where Eni’s presence is significant are South-Central Germany with a 4.4% market share, Spain with 3.2%, Austria with 7.2%, Switzerland with 5.8% and South-Western France with 1.2% on national base.
In recent years, Eni’ s strategy focused on selectively growing its market share, also by means of acquisition of assets, in European areas with interesting profitability perspectives mainly in Central-Eastern Europe (in particular Southern Germany, Austria, the Czech Republic and Hungary) in South-Eastern France and the Iberian Peninsula. In pursuing such growth, Eni has been able to reap synergies deriving from said areas being close to Eni’s production and logistic facilities. Over the past five years, retail volumes of refined products marketed in the rest of Europe have grown more than 50% (equal to a 9% compound average growth rate).
By 2010 Eni expects to market approximately 5.6 bl. Growth in volumes will be achieved through acquisitions, leasing and construction of new service stations with high quality standards,

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automation and throughput, also leveraging on marketing campaigns aimed at enhancing the Agip brand perception on markets.
By 2010 Eni plans to have a network of approximately 2,180 service stations with an average throughput of 2.6 bl. Non-oil activities in the rest of Europe are carried out under the “CiaoAgip” brand name in 1,158 service stations, of these 328 are in Germany and 169 in France with a 60% coverage of the network and the virtually complete coverage of owned stations.

MultiEnergy
The attention paid to environmental considerations led to the construction of Multienergy service stations that are equipped with solar panels able to provide all the energy necessary for their functioning and that sell a full range of fuels with a significant environmental value.
The inauguration of the Agip MultiEnergy service station at the Infraserv Höchst industrial park in Germany, marks the conclusion of the first phase of the “Zero Regio” project, which has the support of the European Commission, for the construction of an innovative “multifuel” station for the supply and trial of zero emission vehicles fuelled with hydrogen.

4. Other businesses

Wholesale marketing and other sales
Eni markets gasoline and other fuels on wholesale markets, including diesel fuel for automotive use and for heating purposes, for agricultural vehicles and for vessels, gasoline and fuel oil. Major customers are wholesalers, agricultural users, manufacturing industries, public utilities and transports.
Eni provides its customers with its expertise in the area of fuels with a wide range of products that cover all market requirements. Along with traditional products provided with the high quality Eni standard, there is also an innovative low environmental impact line, which includes AdvanceDiesel especially targeted for heavy duty public and private transports.
Customer care and product distribution is supported by a widespread commercial and logistical organization present all over Italy and articulated in local marketing offices and a network of agents and concessionaires.
In 2006 volumes marketed on wholesale markets in Italy, which excludes the Avio and Bunker businesses, were 8.22 mmtonnes down 610 ktonnes from 2005, or 7%, due mainly to a decline in domestic consumption related to mild weather conditions in the fourth quarter of the year.
  Sales volumes on wholesale markets outside Italy were 4.27 mmtonnes, up approximately 100 ktonnes from 2005, or 2.6%, reflecting mainly higher sales in Germany and Spain.
Eni also markets jet fuel directly at 38 airports, of which 27 in Italy. In 2006, these sales amounted to 2.18 mmtonnes (of which 1.84 mmtonnes in Italy) up approximately 200 ktonnes.
Eni is active also in the international market of bunkering, marketing marine fuel in 38 ports, of which 23 in Italy. In 2006 marine fuel sales were 1.9 mmtonnes (1.24 in Italy) increasing 100 ktonnes.
Other sales were 22.09 mmtonnes of which 19.48 mmtonnes referred to sales to oil companies and traders, and 2.61 mmtonnes supplies to the petrochemical sector.

LPG
In Italy Eni is leader in LPG production, marketing and sale with 589 ktonnes sold for heating and automotive use (under the Agip brand and wholesale) equal to an 18% market share. Additional 350 ktonnes of LPG were marketed through other channels mainly to oil companies and traders.
LPG activities in Italy are supported by direct production, availability from 11 bottling plants and a number of owned storage sites in addition to products imported at coastal storage sites located in Livorno, Naples and Ravenna.

Lubricants
Eni operates 8 (owned and co-owned) blending plants, in Italy, Europe, North and South America, Africa and the Far East which manufacture finished and fatty lubricants. With a wide range of products composed of over 650 different blends, Eni masters international state-of-the-art know-how for the formulation of products for vehicles (engine oil, special fluids and transmission oils) and industries (lubricants for hydraulic systems, industrial machinery and metal processing).
In Italy Eni is a leader in the manufacture and sale of lubricant bases. Base oils are manufactured primarily at its refinery in Livorno. Eni also owns one facility for the production of additives and solvents in Robassomero.
In 2006, retail and wholesale sales in Italy amounted to 136 ktonnes with a 24.9% market share. Eni also sold approximately 4 ktonnes of special products (white oils, transformer oil and anti-freeze fluids). Outside Italy sales amounted to approximately 102 ktonnes, of these about 50% were registered in Europe (mainly Germany, Netherlands and Spain).

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  Refining system in 2006
   

Ownership share
(%)

 

Conversion equivalent
(%)

 

Primary balanced refining capacity share
(kbbls/g)

 

Primary balanced refining capacity total
(kbbls/d)

 

Fluid catalytic cracking FCC
(kbbls/d)

 

Residue Conversion
(kbbls/d)

 

Go-Finer
(kbbls/d)

 

Mild Hydro- cracking/ Hydro- cracking
(kbbls/d)

 

Visbreaking/ Thermal Cracking
(kbbls/d)

 

Coking
(kbbls/d)

Wholly-owned refineries       58.9   534   534   69   21   36   29   65   47
Italy                                        
     Sannazzaro   100   46.2   170   170   34           29   28    
     Gela   100   143.5   100   100   35       36           47
     Taranto   100   61.1   110   110       21           35    
     Livorno   100   11.4   84   84                        
     Porto Marghera   100   22.8   70   70                   22    
Partially owned refineries (1)       50.9   177   804   172   24   27   55   96    
Italy                                        
     Milazzo   50   72.3   80   160   41   24       33        
Germany                                        
     Ingolstadt/Vohburg/Neustadt
     (Bayernoil)
  20   32.6   52   258   58               33    
     Schwedt   8.33   41.8   19   223   49       27       49    
Czech Republic                                        
     Kralupy/Litvinov
      (Ceska Rafinerska)
  16.3   28.8   27   163   24           22   14    
Total Refineries       57.0   711   1,338   241   45   63   84   181   47
     
(1)   Capacity of conversion plants is 100%.

 

  Refining capacity      

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Balanced capacity at period end (1)   (kbbl/d)   853   859   859   859   814   654   681   681   701   711
Balanced capacity of wholly-owned refineries at period end       664   664   664   664   664   504   504   504   524   534
Processing at wholly-owned refineries       621   681   640   659   645   501   502   535   547   543
Balanced capacity utilization of wholly-owned refineries   (%)   94   103   96   99   97   99   100   100   100   100

 

  Petroleum products availability  

(mmtonnes)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                                             
Italy                                                            
Refinery intake in wholly-owned refineries   31.10     34.05     32.00     32.93     32.24     30.09     25.09     26.75     27.34     27.17  
Refinery intake for third parties   (3.50 )   (3.24 )   (2.78 )   (3.41 )   (1.45 )   (1.88 )   (1.72 )   (1.50 )   (1.70 )   (1.53 )
Refinery intake in non-owned refineries   8.00     7.90     8.08     8.41     5.92     6.27     8.43     8.10     8.58     7.71  
Consumption and losses   (2.00 )   (1.94 )   (2.07 )   (2.11 )   (1.95 )   (1.91 )   (1.64 )   (1.64 )   (1.87 )   (1.45 )
Products available   33.60     36.77     35.23     35.82     34.76     32.57     30.16     31.71     32.35     31.90  
Purchases of finished products and change in inventories   6.75     5.74     5.45     4.30     5.19     6.27     5.86     5.07     4.85     4.45  
Finished products transferred to foreign cycle   (4.20 )   (6.51 )   (5.23 )   (4.58 )   (4.96 )   (5.56 )   (5.19 )   (5.03 )   (5.82 )   (5.35 )
Consumption for power generation                                 (1.74 )   (1.07 )   (1.06 )   (1.09 )   (1.10 )
Sales   36.15     36.00     35.45     35.54     34.99     31.54     29.76     30.69     30.29     29.90  
Outside Italy                                                            
Products available   2.80     3.33     3.08     3.07     3.02     2.98     3.36     4.04     4.33     4.37  
Purchases of finished products and change in inventories   8.45     8.35     8.06     10.27     10.27     12.16     12.12     13.78     11.19     11.51  
Finished products transferred from Italian cycle   4.20     6.51     5.23     4.58     4.96     5.56     5.19     5.03     5.82     5.35  
Sales   15.45     18.19     16.37     17.92     18.25     20.70     20.67     22.85     21.34     21.23  
Sales in Italy and outside Italy   51.60     54.19     51.82     53.46     53.24     52.24     50.43     53.54     51.63     51.13  

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  Petroleum products sales in Italy and outside Italy  

(mmtonnes)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Retail marketing       12.09   12.02   11.85   11.57   11.64   11.14   10.99   10.93   10.05   8.66
Wholesale marketing       11.3   11.73   11.42   11.1   11.24   10.64   10.35   10.7   10.48   10.06
        23.39   23.75   23.27   22.67   22.88   21.78   21.34   21.63   20.53   18.72
Petrochemicals       5.97   5.75   5.38   4.93   4.23   3.82   2.79   3.05   3.07   2.61
Other sales (1)       6.79   6.5   6.8   7.94   7.88   5.94   5.63   6.01   6.69   8.57
Sales in Italy       36.15   36   35.45   35.54   34.99   31.54   29.76   30.69   30.29   29.90
Retail marketing rest of Europe       2.25   2.35   2.36   2.35   2.47   2.57   3.02   3.47   3.67   3.82
Retail marketing Africa and Brazil       0.68   1.11   1.55   1.43   1.71   1.44   1.18   0.57        
        2.93   3.46   3.91   3.78   4.18   4.01   4.2   4.04   3.67   3.82
Wholesale marketing outside Italy       6.17   6.2   6.4   5.46   5.55   5.65   6.01   5.3   4.50   4.60
        9.1   9.66   10.31   9.24   9.73   9.66   10.21   9.34   8.17   8.42
Other sales (1)       6.35   8.53   6.06   8.68   8.52   11.04   10.46   13.51   13.17   12.81
Sales outside Italy       15.45   18.19   16.37   17.92   18.25   20.7   20.67   22.85   21.34   21.23
        51.6   54.19   51.82   53.46   53.24   52.24   50.43   53.54   51.63   51.13
     
(1)   Includes bunkering consumption for power production (until 2001) and sales to oil companies. From 2002, includes also sales of MTBE.

 

  Retail and wholesale sales by product in Italy and outside Italy  

(ktonnes)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy                                            
Retail sales       12.09   12.37   11.85   11.57   11.64   11.14   10.99   10.93   10.05   8.66
     Gasoline       7.68   7.76   7.23   6.74   6.53   5.98   5.49   5.09   4.35   3.38
     Gasoil       3.92   4.12   4.22   4.43   4.74   4.83   5.23   5.61   5.49   5.09
     LPG       0.45   0.46   0.37   0.38   0.35   0.31   0.26   0.22   0.20   0.18
     Lubricants       0.04   0.03   0.03   0.02   0.02   0.02   0.01   0.01   0.01   0.01
Wholesale sales       11.30   11.38   11.42   11.10   11.24   10.64   10.35   10.70   10.48   10.06
     Gasoil       4.82   4.95   5.01   4.85   5.12   4.88   4.78   4.89   4.86   4.60
     Fuel oil       2.64   2.56   2.25   2.15   2.12   2.05   1.66   1.80   1.50   1.27
     LPG       0.55   0.50   0.50   0.48   0.48   0.46   0.45   0.46   0.46   0.41
     Gasoline       0.13   0.08   0.24   0.21   0.17   0.16   0.17   0.15   0.16   0.15
     Lubricants       0.17   0.16   0.15   0.16   0.15   0.14   0.13   0.13   0.13   0.13
     Other       2.99   3.14   3.27   3.25   3.20   2.94   3.16   3.27   3.37   3.50
Outside Italy (retail + wholesale)                                            
     Gasoline       2.28   2.28   2.39   2.16   2.39   2.27   2.37   2.32   2.14   2.06
     Gasoil       3.49   3.83   4.01   3.92   4.30   4.49   5.10   4.96   4.71   4.90
     Jet fuel       0.52   0.35   0.43   0.47   0.43   0.39   0.39   0.47   0.34   0.34
     Fuel oil       0.38   0.33   0.26   0.26   0.22   0.21   0.20   0.15   0.12   0.23
     Lubricants       0.15   0.11   0.12   0.13   0.11   0.13   0.16   0.11   0.10   0.10
     LPG       1.71   1.79   1.86   1.86   1.82   1.78   1.72   1.09   0.44   0.46
     Other       0.57   0.98   1.25   1.14   0.47   0.41   0.27   0.24   0.32   0.33
Total       9.10   9.66   10.31   9.94   9.73   9.67   10.21   9.34   8.17   8.42

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Contents

ENI FACT BOOK / REFINING & MARKETING - MAIN DATA

  Number of service stations  

(units)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       10,615   9,828   9,425   9,045   8,351   7,710   7,290   7,244   4,349   4,356
     ordinary stations:       10,345   9,563   9,160   8,783   8,157   7,546   7,134   7,097   4,204   3,194
     - Agip brand       6,519   6,044   5,772   5,561   5,374   4,954   4,215   4,186   4,204   3,194
     - IP brand       3,826   3,519   3,388   3,222   2,783   2,592   2,919   2,911        
     highway stations:       270   265   265   262   194   164   156   147   145   142
     - Agip brand       192   189   189   189   152   127   146   143   145   142
     - IP brand       78   76   76   73   42   37   10   4        
Outside Italy       2,141   3,156   3,064   3,040   3,356   3,052   3,357   1,896   1,933   1,938
     Central Europe       1,112   1,081   1,044   1,007   988   1,013   1,230   1,309   1,318   1,329
     Iberian Peninsula       186   192   200   201   202   198   357   356   373   358
     Eastern Europe       121   142   145   165   185   223   226   231   242   251
     Africa       722   685   593   262   262                    
     Latin America           1,056   1,082   1,405   1,719   1,618   1,544            
        12,756   12,984   12,489   12,085   11,707   10,762   10,647   9,140   6,282   6,294

 

  Average throughput  

(kl/number of service stations)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Italy       1,405   1,475   1,530   1,565   1,643   1,707   1,813   1,863   1,770   2,463
Rest of Europe       2,042   2,141   2,200   2,210   2,303   2,276   2,378   2,393   2,426   2,486
Brazil           1,122   1,074   856   914   967   942            
Africa       926   1,080   1,079   1,515   1,943                    
Average throughput outside Italy       1,753   1,661   1,586   1,524   1,563   1,585   1,671   2,393   2,426   2,486
Average throughput       1,463   1,512   1,543   1,555   1,621   1,674   1,771   1,970   1,926    
Average throughput Agip branded network       1,522   1,560   1,606   1,615   1,685   1,861   2,109   2,488   2,479   2,470
     Italy       1,450   1,519   1,616   1,662   1,757   2,014   2,410   2,527   2,509   2,463
     Outside Italy       1,753   1,662   1,586   1,524   1,563   1,585   1,671   2,393   2,427   2,486

 

  Market shares in Italy  

(%)

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                             
Retail       43.4   41.7   41.0   40.2   39.7   37.5   36.6   36.3   29.7   29.3
Gasoline       43.9   42.4   41.4   40.6   40.1   37.7   36.2   35.5   27.5   27.2
Gasoil       43.3   42.3   41.7   41.3   40.9   38.6   38.4   38.2   32.3   31.6
LPG (automotive)       37.7   27.9   28.3   26.6   25.4   23.8   22.0   20.0   17.9   18.1
Wholesale       23.1   23.3   24.4   24.0   25.6   23.9   24.1   27.0   28.0   26.9
Gasoil       35.5   35.5   35.0   34.5   35.4   34.7   33.1   33.0   32.8   31.2
Fuel oil       11.0   10.8   11.6   12.9   14.9   13.3   12.6   17.7   17.9   15.2
Domestic market share       30.5   30.1   30.9   30.4   31.5   29.5   29.5   31.3   29.0   28.2
Total market share (retail + wholesale)                                            
     Gasoline       43.9   43.6   42.2   41.3   40,8   38.3   36,8   36.0   28.2   27.8
     Gasoil       38.6   38.5   38.0   37.6   38.1   36.8   35.9   35.9   32.8   31.7
     LPG       29.8   24.8   22.9   22.0   22.0   20.9   19.4   19.1   18.8   18.0

 

  Retail market shares outside Italy  

(%)

 

     

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                         
Central Europe                                        
Austria       8.1   7.7   7.1   7.7   8.1   8.2   8.0   7.4   7.2
Switzerland       6.4   6.6   6.8   6.4   6.0   5.7   5.7   5.7   5.8
Germany       2.6   2.6   2.6   2.7   2.6   3.1   3.8   4.1   4.4
France       0.4   0.4   0.4   0.6   0.8   1.1   1.2   1.1   1.2
Eastern Europe                                        
Hungary       4.5   4.3   4.1   4.5   6.1   6.7   6.4   6.0   6.3
Czech Republic       4.2   4.3   4.3   4.3   5.7   4.9   5.2   5.5   5.9
Romania       1   0.9   1   1.1   1.1   0.9   ..   ..   ..
Slovenia                           1.0   1.3   1.7    
Iberian Peninsula                                        
Spain       1.7   1.7   1.8   1.6   1.6   2.2   3.0   3.1   3.2
Portugal       2.1   2   1.7   1.6   1.5   0.9   1.0   0.9   0.7

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Contents

ENI FACT BOOK / ENGINEERING & CONSTRUCTION

                 
  Key performance indicators  

2004

 

2005

 

2006

 
  Net sales from operations (a)  

(million euro)

 

5,696

 

5,733

 

6,979

 
  Operating profit      

203

 

307

 

505

 
  Adjusted operating profit      

215

 

314

 

508

 
  Adjusted net profit      

252

 

328

 

400

 
  Capital expenditure      

186

 

349

 

591

 
  ROACE adjusted   (%)  

10.5

 

12.0

 

12.8

 
  Orders acquired:   (million euro)  

5,784

 

8,395

 

11,172

 
  - Offshore construction       2,867   3,096   3,681  
  - Onshore construction       2,535   4,720   4,923  
  - Offshore drilling       107   367   2,230  
  - Onshore drilling       275   21   338  
  Order backlog:      

8,521

 

10,122

 

13,191

 
  - Offshore construction       3,420   3,721   4,283  
  - Onshore construction       4,488   5,721   6,285  
  - Offshore drilling       317   382   2,247  
  - Onshore drilling       296   298   376  
  Employees at year end  

(unit)

 

25,819

 

28,684

 

30,902

 
       
  (a)   Before elimination of intersegment sales.
       

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Contents

ENI FACT BOOK / ENGINEERING & CONSTRUCTION

STRATEGIES
Eni operates in engineering, oilfield services and construction both offshore and onshore through Saipem, a company listed on the Italian Stock Exchange (Eni’s interest 43%). Saipem boasts a strong competitive position in the relevant markets thanks to technological and operational skills, engineering and project management capabilities and ability to operate in complex environments, owing also to the integration with Snamprogetti. Leveraging on these strengths and rising demand for drilling equipment and oilfield services, Saipem intends to carry out the following fundamental strategies:

In order to carry out these strategies, Saipem expects to invest approximately euro 3.5 billion to further expand the geographical reach and operational features of its world-class fleet over the next four years.

 

2006 Highlights

Adjusted net profit was euro 400 million, up euro 72 million from a year ago or 22%, reflecting a better operating performance against the backdrop of favorable trends in the demand for oilfield services.

Return on average capital employed calculated on an adjusted basis was 12.8% in 2006, up 12% from 2005.

Orders acquired amounted to euro 11,172 million, up euro 2,777 million from 2005 (+33.1%), in particular in onshore activities.
  Order backlog was euro 13,191 million at December 31, 2006 (euro 10,122 million at December 31, 2005).

In February 2007, a contract for the construction of a new pipelayer has been signed. The unit, with a carrying capacity of 25 ktonnes and a lifting capacity of 600 tonnes by means of crane, will be manufactured in China.

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ENI FACT BOOK / ENGINEERING & CONSTRUCTION - BUSINESS AREAS

 

 

Dimensions:
Length:
198 m
Breadth:
87 m
Depth to main deck: 45 m
Transit draft: 10.5 m
Operational draft:
27.5 m

Dynamic positioning: DP (AAA) Lloyds Register; IPD 3 R.I.Na.; Class 3 Norwegian Maritime Directorate notations. Power plant: total power plant 70,000 kW, 10,000 Volt; 12 diesel generators on heavy fuels divided in 4 fire segregated engine rooms; classified UMS. Ballast system: computer controlled system with simultaneous capabilities comprising 4 x 6,000 t/h ballast pumps, fully redundant.
  Lifting facilities main crane: 2 twin S 7000 model fully revolving bow mounted Amhoist cranes; main blocks tandem lift: 14,000 t; main block single lift: 7,000 t revolving at 40 m rad./41 m; tieback 6,000 t revolving at 45 m rad./50 m. Lowering capability to 450 m below sea level. Whip hook: 120 t revolving at 150 m rad. J-Lay system: pipe diameter range from 4” to 32”; main laying tension system 525 t with tensioners, up to 2,000 t with friction clamps; laying tower angle 90º-110º; number of welding stations: 1; pipe storage capacity up to 6,000 t. Maximum laying depth: 3,000 m.   Dimensions:
Length overall:
152 m
Breadth: 65 m
Depth to main deck: 29.8 m
Operational draft:
7.8-15.5 m
Deck load capacity:
up to 3,600 t

Propulsion/positioning system: number of thrusters: 4 azimuthal variable pitch. Thruster capacity: 2,060 kW/37 t thrust. Pipe tensioning system: type of tensioners: Remacut DC electric; tensioner capacity: 3 x 110 t each; pipe diameter capacity: up 60”. Pipe abandonment/retrieval system: type of winch: Tesmec DC electric; winch capacity: 300 t constant tension. Cranes/pipe handling system: number of cranes: 2 fully revolving; crane type: deck mounted; crane capacity: 60 t with 50 m boom. Maximum laying depth: 1,150 m.

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Contents

ENI FACT BOOK / ENGINEERING & CONSTRUCTION - BUSINESS AREAS

Business areas

Offshore construction
Saipem has gained a sound competitive positioning in the market of large, complex projects for the development of offshore hydrocarbon fields leveraging on its technical and operational skills, supported by a world-class fleet, the ability to operate in complex environments, and engineering and project management capabilities acquired on the market over recent years. Saipem intends to enhance its market share by means of strengthening its EPIC oriented business model and its relationships with major oil companies and NOCs. Higher levels of profitability are expected to be achieved through outsourcing certain engineering and building activities to low cost centers. Investments will be focused on constantly upgrading and improving technical characteristics and capabilities of Saipem’s world-class fleet, and to build local construction centers.

  In 2006, revenues were euro 3,033 million accounting for 43% of total revenues. This business delivered a gross margin of euro 366 million, corresponding to 55% of total gross margin, higher than the euro 296 million result reported in 2005. This increase reflected higher activity in the Caspian region and Nigeria.

Among the major orders acquired in 2006 were:
  • a contract for the conversion of an oil tanker into an FPSO unit with production capacity of 1.8 mmbbl for the development of the offshore Gimboa field in Angola for Sonangol P&P;
  • an EPIC contract for Burullus Gas Co for the construction of underwater systems for the development of eight new wells within the expansion plan of the Scarab/Saffron and Simian fields offshore in the Nile Delta;
  • an EPIC contract for CNR International Limited for the construction of three wellhead towers, a support platform, and interconnecting pipelines and umbilicals within the development of the offshore Olowi field in Gabon.

Dimensions:
Length overall:
148.5 m
Breadth overall:
54.9 m
Depth to main deck: 2.8 m
Maximum deck load: 5,700 t

Pipelay equipment: 3 x 75 t tensioners, 11 work stations (welding, x-ray and field joint coating). Double jointing system with 8 work stations. Above water tie-in capability (optional). Dual lay welding line and ramp (optional). Abandonment and recovery winch: 275 t. Lifting facilities: fitted with 4 revolving pedestal cranes (1 x 318 t and 3 x 37 t) mounted at each corner of the main deck for pipe handling and general lifting. Pipe handling davits may also be mounted on the main deck to facilitate above water tie-ins. “S-lay” technique. Pipe diameter: max 60”. Maximum laying depth: 600 m.
  Dimensions:
Length overall:
156 m
Breadth: 30 m
Operational draft:
12.4 m
Displacement:
26,608 t at operating draft
Payload: 4,300 t at 7.40 draft

Dynamic Positioning: Dynpos Autro, Dynpos Autr, 2 DGPS, 2 Lras HIPAP - 2,500 m interfaces available for Taut Wire, Artemis, Fan Beam. Lifting capabilities: main crane AMClyde KPT660: main hook SWL: 600 t at 30 m, 300 t at 55 m; auxiliary cranes: 2 Liebherr CBO3100-50 Litronic SWL 50 t at 20 m, SWL 30 t at 38 m; 2 Liebherr RL-S 20/20 Litronic; starboard side fixed boom SWL 20 t at 20 m, portside telescopic boom SWL 15 t at 16 m. Pipelay equipment: 5 work stations + one in option; rigid pipe: 4 pipes string J-lay tower system, SWL 320 t, 3,000 m w.d., max. o.d. 22”; flexible pipe: laying through Gutter and 3 x retractable four tracks tensioners total SWL 270 t, max. i.d. 17”. Assembly station has openings to allow the passage of 4 x 3 x 6 m special items.

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ENI FACT BOOK / ENGINEERING & CONSTRUCTION - BUSINESS AREAS

Offshore construction
Saipem operates in the construction of plants for hydrocarbon production (separation, stabilization, collection of hydrocarbons, pumping stations, water injection) and treatment (removal and recovery of sulphur dioxide and carbon dioxide, fractioning of gaseous liquids, recovery of condensates) and in the installation of large onshore transport systems (pipelines, compression stations, terminals). Saipem intends to capture opportunities arising from expected increasing demand from oil majors, by leveraging on its solid competitive position and integration with Snamprogetti engineering capabilities.
In 2006, revenues were euro 3,333 million accounting for 48% of total revenues. Gross margin came in at euro 147 million as compared to euro 73 million in 2005. This increase reflected higher activity levels related essentially to the start-up of certain large projects acquired in 2005.
  Among the major orders acquired in 2006 were:
  • an EPC contract for Saudi Aramco for the construction of four trains for gas and crude;
  • separation with a total capacity of 1.2 mmbbl/d and production facilities within the development of the onshore Khursaniyah field in Saudi Arabia;
  • an EPC contract for Shell Petroleum Development Company of Nigeria for the laying of pipelines, flowlines and composite fibre optic and high voltage electrical cables within the development Gbaran project. The contract was won in consortium with Desicon Engineering Ltd;
  • an EPC contract for Canaport LNG for the construction of a regasification terminal, inclusive of auxiliary facilities for gas offloading, pumping, vaporization and transmission, in addition to two storage tanks. The contract was won in consortium with the Canadian company SNC - Lavalin.

Dimensions:
Hull length: 60.8 m
Beam: 56.5 m
Depth:
6.7 m
Length of legs (including footing): 126.1 m

Operating performance:
Drilling depth:
 6,500 m
Water depth max: 90 m
Variable load:
1,500 t
  Dimensions:
Length overall:
228 m
Breadth, moulded: 42 m
Depth, moulded:
19 m
Operating draft: 12 m
Displacement:
96,455 t
Variable load: over
20,000 t
Oil storage capacity:
140,000 bbl

Operating performance:
Drilling depth:
9,200 m
Water depth max:
3,000 m

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ENI FACT BOOK / ENGINEERING & CONSTRUCTION - BUSINESS AREAS

Offshore drilling
Saipem provides offshore drilling services to oil companies mainly in West Africa, the North Sea and the Mediterranean Sea. It boasts significant market positions in the most complex segments of deep and ultra-deep offshore leveraging on the outstanding technical features of its drilling platforms and vessels, capable of drilling holes at a maximum depth of 9,200 meters. Demand for drilling services is expected to increase in future years reflecting exploratory plans of oil majors, leading to a substantial rise in tariffs due to equipment shortage. In view of this, Saipem is planning to built a new drilling rig capable of reaching a 10,000 meter drilling depth. In 2006, revenues were euro 365 million accounting for 5% of total revenues. Gross margin amounted to euro 119 million as compared to euro 65 million in 2005.
  This increase was supported by higher tariffs for the Scarabeo 3 and Scarabeo 5 semi-submersible platforms and higher activity levels of the Perro Negro 5 jack-up and Scarabeo 4 semi-submersible platform.

The most significant contracts awarded during the period include:
  • a 16-month long contract for the use of the semisubmersible drilling platform Scarabeo 7 in Nigeria for ExxonMobil;
  • a 49-month long contract for the use of the semisubmersible drilling platform Scarabeo 5 in Norway for Statoil;
  • a 27-month long contract for the use of the semisubmersible drilling platform Scarabeo 3 in Nigeria for Addax Petroleum.

Dimensions:
Pontoon length:
 111 m
Pontoon breadth: 14.3 m
Pontoon height:
9.5 m
Main hull length: 80.8 m
Main hull breadth:
68.8 m
Main hull depth: 7.3 m

Operating performance:
Dynamic assisted mooring
up to 900 m w.d.
Dynamic positioned mode
up to 2,000 m w.d.
Maximum drilling depth: 9,000 m
Water depth max:
2,000 m
4,300 t variable deck load in all conditions, under the most stringent codes.
  Dimensions:
Displacement:
38,100 t
Main deck width: 61.3 m
Main deck length
77.5 m
Main deck depth: 4.5 m
Variable deck load:
4,000 t

Operating performance:
Drilling depth W/5” DP: 25,000 ft
Drilling depth:
8,000 m
Water depth max: 1,500 m
Positioning system: automatic thruster assisted 8 leg mooring system.

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ENI FACT BOOK / ENGINEERING & CONSTRUCTION - BUSINESS AREAS

Onshore drilling
Saipem operates in this area as main contractor for the major international oil companies executing its activity mainly in Saudi Arabia, North Africa and Peru, where it can leverage on its knowledge of markets, long-term relations with customers and integration with other business areas.
  In 2006, revenues were euro 248 million accounting for 4% of total revenues. Gross margin amounted to euro 38 million as compared to euro 26 million in 2005, reflecting a higher activity level.
The contracts awarded during the period amounted to euro 338 million.

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Contents

ENI FACT BOOK / ENGINEERING & CONSTRUCTION

  Main operating data  

  

 

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Offshore pipelines laid   (km)   1,610   2,009   979   276   781   1,798   1,409   1,634   883   1,514
Onshore pipelines laid   (km)   1,221   873   1,303   483   552   687   612   465   1,005   871
Offshore structures installed   (tonne)   108,745   65,331   111,164   57,087   73,028   55,960   118,211   172,664   134,602   120,453
Onshore structures installed   (tonne)   36,024   30,514   30,767   13,000   18,120   30,060   29,930   15,888   7,112   5,242
Offshore drilling   (km)   99   94   88   96       125   129   130   114   126
Onshore drilling   (km)   178   167   63   147   190   348   386   455   548   599
Offshore wells drilled   (unit)   25   52   53   50   36   50   59   59   67   75
Onshore wells drilled   (unit)   43   78   30   44   55   100   119   150   213   236

 

Construction vessels
Name   Type  

Laying technique

 

Transport/lifting capability
(t)

 

Maximum laying depth
(m)

 

Pipelaying maximum
diameter
(inches)

Castoro 2   Derrick/lay barge      

1,000

     

60

Castoro 6   Semi-submersible large diameter pipelay vessel  

S

 

300

 

1,150

 

60

Castoro 8   Crane and pipelay vessel  

S

 

2,177

 

600

 

60

Castoro 9   Launching/cargo barge      

5,000

       
Castoro 10   Trench/pipelay barge          

300

 

40

Castoro XI   Launching/cargo barge      

15,000

       
Crawler   Derrick/lay barge      

540

     

48

Saipem 3000   Multipurpose monohull crane, DP (J, S, reel-lay) and lifting vessel  

Reel, J, S

 

2,200

 

3,000

 

6

S. 42   Launching/cargo barge      

8,000

       
S. 44   Launching/cargo barge      

30,000

       
S. 45   Launching/cargo barge      

20,000

       
Saipem 7000   Semi-submersible crane and pipelaying (J-lay) DP vessel  

J

 

14,000

 

3,000

 

32

Semac 1   Semi-submersible pipelay barge  

S

 

318

 

600

 

58

BAR Protector   DP dive support vessel                
Saibos FDS   Multipurpose monohull dynamically positioned crane and pipelay (J-lay) vessel for the development of hydrocarbon fields in deep water  

J

 

600

 

3,000

 

22

Saibos 230   Mobile crane barge for small-diameter pipelaying                
Saibos 103   Launching/cargo barge                
BOS 600   Launching/cargo barge      

30,000

       
BOS 355   Crane and pipelay vessel      

540

     

48

C12   Pipelay vessel          

1.4

 

40

Trenching barge   Trench/cargo barge          

1.4

 

40

ERSAI 1   Crane vessel      

1,600

       

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ENI FACT BOOK / ENGINEERING & CONSTRUCTION

Drilling vessels
Name   Type   Drilling plant   Maximum depth
(m)
  Drilling maximum
(m)
  Other   Crew number maximum (unit)
Perro Negro 2   Self elevating, triangular mobile drilling unit (Jack up)   Oilwell E 2000   90   6,500   Heliport provided   112
Perro Negro 3   Self elevating cantilever drilling platform (Jack up)   Ideco E 2100   90   6,000   Heliport provided   87
Perro Negro 4   Self elevating drilling platform (Jack up)   National 110 UE   45   5,000   Heliport provided   60
Perro Negro 5   Self elevating drilling platform (Jack up)   National 1320 UE   90   6,500   Heliport provided   72
Scarabeo 3   Semi-submersible drilling platform helped propulsion system   National 1625 DE   550   7,600   Heliport provided   90
Scarabeo 4   Semi-submersible drilling platform helped propulsion system   National 1625 DE   550   7,600   Heliport provided   90
Scarabeo 5   Semi-submersible drilling platform helped propulsion system   Emsco C 3   1,900   8,000   Heliport provided   100
Scarabeo 6   Semi-submersible drilling platform helped propulsion system   Oilwell E 3000   500   7,600   Heliport provided   91
Scarabeo 7   Semi-submersible drilling platform helped propulsion system   Wirth SH 3000 EG   1,500   8,000   Heliport provided   107
Saipem 10000   Ultra deep water drillship, self propelled, dynamic positioning   Wirth GH 4500 EG   3,000   9,200   Oil storage capacity: 140,000 bbl; heliport provided   160

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ENI FACT BOOK / TECHNOLOGICAL INNOVATION

Technological innovation

Eni’s commitment to technological research and innovation underscores a fundamental belief that technology is key to increase our competitive advantage over the long term and promoting sustainable growth. Future global challenges require ingenuity and commitment: from the environmental and climate issues to the increasingly difficult access to hydrocarbon reserves large, but mainly controlled by producing countries; from the identification of relevant discontinuities in the production of energy from renewable sources to the optimization of production processes up to solution of problems existing in countries where Eni has been present for a long time or where it recently entered.
Eni is conducting research aimed primarily at reducing the costs of finding and recovering hydrocarbons, upgrading heavy oils, monetizing stranded gas and protecting the environment. Over the next four years Eni intends to invest 1.5 billion euros to support its research and development (R&D) strategy. More specifically, Eni’s main R&D fields regard:
  • reserve replacement and reduction of mineral risk;
  • production and monetization of non-conventional hydrocarbon reserves and optimal management of reserves with high hydrogen sulphide and sulphur content;
  • delivering more gas to market, monetizing associated gas and stranded gas;
  • improvement of fuel quality and performance in light of the evolution of engines to increasingly perfected and efficient systems with lower impact on the environment; and
  • efficient use of fossil fuels through an improvement in refining yields and an optimal use of each fuel entailing a lower environmental impact.
  Referring to environmental protection, Eni intends to develop the “Along with Petroleum” program aimed at identifying and developing research projects on the most advanced aspects of large scale use of renewable energy sources and energy efficiency. In particular, Eni expects to devote a great deal of focus on the fields of the mitigation of the greenhouse effect, through the capture and geological sequestration of carbon dioxide, the bio-fuels, the photovoltaic, the solar energy and the hydrogen production by renewable sources.
In 2006 Eni invested euro 222 million (204 in 2005), of these 39% were directed to the Exploration & Production segment, 32% to the Refining & Marketing segment, 22% to the Petrochemical segment and 7% to the Engineering & Construction segment.
At December 31, 2006, a total of 1,160 persons were employed in research and development activities.
In 2006 a total of 39 applications for patents were filed.
A description of the main technologies under development or currently applied is provided below.

Main technological innovation projects

Advanced Drilling Systems and Well Testing

Eni developed significant industrial applications of innovative technologies enabling to drill highly complex wells with greater operating efficiency.
The “Geosteering” project developed by Eni in joint venture with Shell aims at the development of technologies capable of providing geological information on not yet drilled layers, (around the scalpel up to the surface) while drilling.

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ENI FACT BOOK / TECHNOLOGICAL INNOVATION

 

In the first six months of 2006, various down hole prototypes have been made and in the second half of the year the technology was tested in a well. Testing is expected to continue until the first half of 2007.
Referring to drilling activities, some new technologies have been tested:
  • Extreme Lean Profile, development of “slim” field techniques applicable also to fields with narrow diameter;
  • Eni Circulation Device, avoiding the danger of “keep of the bars” during the drilling activity;
  • Light Drill Pipe, based on the usage of aluminum bars in strongly deviated wells;
  • Zero Emission Well Testing, evaluation methodology of the characteristics of a new field by fluids injection (that is to say with no emission) based on know-how and Eni’s software, instead of on conventional production tests prove “in hydrocarbons supplying”.


Numeric and High Resolution Geophysical Prospecting Techniques

The development of a simulator of oil systems “Steam 3D” has been completed. It enables to describe the evolution of complex geological structures in time. Development continued of the proprietary CRS technology (3D Common Reflection Surface Stack) that aims at allowing prospecting in areas characterized by low seismic response.
First application of the following technologies has been done:

  • CSEM (Controlled Source ElectroMagnetic), which enables data collecting on the presence of pre-drilling hydrocarbons, reducing explorative risk and improving the reliability in the definition of the reservoir extension, through the measurement of the electric drag of structure in the sea field;
 
  • “Multipoint Statistic” and “Process Oriented Modelling” improving the characterization and the localization of reserve that can be produced from a specific reservoir;

  • “Integrated Asset Modelling”, which optimizes the development and the production of a field through the integration of field models and on-shore facilities;

  • Regarding to the production optimization in “tight reservoirs”, first application of a proprietary technology has been made aiming to foresee the increase of productivity achievable by operations on induced fractures.


Sulphur management

In 2006 the integrated research program Sulphur and H2S management in E&P operations related to the handling of gas with high H2S content has been completed. An innovative proprietary system called Concrete Wall for the massive storage of sulphur and a bulk removal technology of H2S have been developed. In 2007 demonstration facilities for the handling and storage of sulphur are expected to be developed along with a study regarding the behavior of materials in very sour environments and under extreme pressure and temperature conditions.

Gas to Liquids (GTL)

The conversion of gas to liquids is a key technology for the use of natural gas on a large scale for the production of high quality fuels, in particular diesel fuel and therefore it receives special attention by all oil majors due to its strategic value.

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ENI FACT BOOK / TECHNOLOGICAL INNOVATION

In 2006 in cooperation with IFP/Axens, Eni completed the technology handbook for this proprietary technology for the conversion of gas to liquids via Fischer-Tropsch synthesis and the basic engineering of a 37 kbbl/d industrial unit.
In 2007 some issues will be addressed regarding the risks of the transition to the subsequent industrial scale:
  • mechanic validation on the maximum industrial scale of the catalyst for the FT synthesis;
  • validation of the mechanic design carried out by referenced builders of the reactor to be applied to the maximum industrial scale;
  • tweak of a scheme on the treatment of water produced in the synthesis process.
  Conversion of heavy crude and fractions into light products

Testing continued at the Taranto demonstration plant of Eni’s proprietary technology EST, a process of catalytic hydroconversion in the slurry phase of non conventional crude, extra heavy crude and refining residues that allows to convert asphaltenes (the hard fraction of heavy crude) totally into naphtha, kerosene, diesel fuel. In particular, a four-month test period has been carried out using a residue from a Canadian tar sand, confirming expected conversion yields and performance stability. In 2007 Eni plans to complete the collection of information for designing and building its first industrial plant.

 

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ENI FACT BOOK / TECHNOLOGICAL INNOVATION

Taranto demonstration plant of Eni’s proprietary technology EST

SCT-CPO Project (Short Contact Time - Catalytic Partial Oxidation)

At the Milazzo research center the SCT-CPO (partial catalytic oxidation with short contact time of liquid and gaseous hydrocarbons) technology has been validated on the pilot scale for producing hydrogen at competitive costs, also in medium to small sized plants with higher flexibility as compared to refinery feedstocks. In 2007 Eni plans to complete the collection of information for designing and building its first industrial plant.


Natural gas high pressure transport (TAP)

The TAP project will contribute to developing the most advanced long distance, high capacity, high pressure and high grade solutions with relevant targets related to:

  • transport on distances over 3,000 kilometers;
  • natural gas volumes to be transported of about 20-30 bcm/year;
  • pressure equal to or higher than 15 MPa;
  • use of high and very high grade steel.

The TAP technology is expected to allow a decrease in the consumption of natural gas used in compressor stations.

  In 2006 testing continued on two infrastructures:
  • one made of steel at a high resistance X80, with a length of about 10 km integrated in the system of Snam Rete Gas;
  • two pilot portions (750 meters of length) made of steel at a high resistance X100, run at a constant pressure in a range of 135 to 150 bar.

After completing the pressure test on these two pilot portions, a test spreading a cracking on one of them has been scheduled.
In 2006 the first technology handbook version was published and a hypothetical 3,400-kilometer long gasline in X100 steel from the Karachaganak field (western Kazakhstan) was designed.


Environmental protection

In 2006 continued the development of technological solutions aimed at minimizing the environmental impact of the exploration, refining and utilization of hydrocarbon.
Referring to the CO2 conversion in energy vectors via biofissation, in 2007 will be evaluated the opportunity to test it on a demonstrative scale.
Among the main activities undertaken or started in 2006, the following projects are highlighted:

  • Green Diesel – the project aims at the production of biodiesel in refineries by means of a new hydrocracking process using vegetable oils and will be developed in cooperation with an international partner;
  • Ensolvex – aimed at the further industrial application of the process for the reclaiming of soils polluted by organic substances;
  • EWMS (Early Warning Monitoring System) – in-field application of the outcome of research on remote monitoring and advanced control.


GHG Project (Green House Gases)

Work continued on the integrated Green House Gases research program, aimed at verifying the industrial feasibility of the geological sequestration of CO2 in depleted fields and salty aquifers. The technical feasibility study of the geological sequestration of CO2 has been completed and in 2007, Eni expects to start testing in the field.

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ENI FACT BOOK / TECHNOLOGICAL INNOVATION

Reformulation of fuels and lubricants

Eni continued its program to improve its “Blue” fuel line of products (BluDiesel and BluSuper). It also started a new phase of its clean diesel fuel program aiming at identifying the optimal formula for a diesel fuel with high performance and low particulate emissions using as benchmark GTL Fischer-Tropsch diesel oil (obtained from the conversion of natural gas into liquids - GTL project). Research activities will be conducted on the design of refining facilities for producing this product.
A process of hydro-dearomatization of certain refining feedstock with a high content of aromatics (e.g. the light cycle oil produced by fluid catalytic crackers) is being developed. A double-function, proprietary catalyst has been developed able to reduce hydrogen consumption and certain by-products. The project is progressing on a pilot scale.
Monitoring on the mock-up distribution of the “ADBlue” in the Agip corner sale, at Assago Ovest (MI) continued. The ADBlue (Water solution with urea at 32.5%) can be used to remove nitrogen oxide (NOx)
  from exahaust gas of Diesel commercial motors with catalytic disposal for the selective reduction of NOx (Selective Catalytic Reactor).

Bio fuel and heavy crude conversion: deal with Petrobras
As part of the development of technologies aiming at the enhancement of fuel quality and at the conversion of heavy crude and fractions into light products, in March 2007 Eni signed an agreement with Petrobras, the world’s leading company in the large-scale production of bio-ethanol. The two partners will combine their proprietary technologies to jointly develop projects for the production of bio-fuels in other countries.
In addition, they will study joint projects to assess the application of the Eni Slurry Technology (EST) in Brazil in the framework of a broader partnership involving both upstream and downstream joint initiatives.

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ENI FACT BOOK / FINANCIAL DATA

   Result of operations  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Net sales from operations   31,359     28,341     31,008     47,938     49,272     47,922     51,487     57,545     73,728     86,105  
Other income and revenues   616     727     952     905     921     1,080     913     1,377     798     783  
Total revenues   31,975     29,068     31,960     48,843     50,193     49,002     52,400     58,922     74,526     86,888  
Purchases, services and other   (19,811 )   (18,033 )   (20,000 )   (31,442 )   (32,110 )   (31,893 )   (34,566 )   (38,347 )   (48,567 )   (57,490 )
Payroll and related costs   (3,051 )   (2,917 )   (2,782 )   (2,786 )   (2,927 )   (3,103 )   (3,166 )   (3,245 )   (3,351 )   (3,650 )
Total operating costs   (22,862 )   (20,950 )   (22,782 )   (34,228 )   (35,037 )   (34,996 )   (37,732 )   (41,592 )   (51,918 )   (61,140 )
Depreciation, amortization and writedowns   (3,768 )   (4,308 )   (3,698 )   (3,843 )   (4,843 )   (5,504 )   (5,151 )   (4,931 )   (5,781 )   (6,421 )
Operating profit   5,345     3,810     5,480     10,772     10,313     8,502     9,517     12,399     16,827     19,327  
Net financial (expense) income   (229 )   (41 )   10     64     (295 )   (167 )   (154 )   (156 )   (366 )   161  
Net (expense) income from investments   59     396     89     33     (7 )   43     (17 )   820     914     903  
Net extraordinary (expense) income   (198 )   (245 )   (528 )   (512 )   1,737     (29 )   49                    
Profit before income taxes   4,977     3,920     5,051     10,357     11,748     8,349     9,395     13,063     17,375     20,391  
Income taxes   (2,254 )   (1,450 )   (2,054 )   (4,335 )   (3,529 )   (3,127 )   (3,241 )   (5,522 )   (8,128 )   (10,568 )
Tax rate (%)   45.3     37.0     40.7     42.1     30.0     37.5     34.5     42.3     46.8     51,8  
Net profit pertaining to:   2,723     2,470     2,997     6,022     8,219     5,222     6,154     7,541     9,247     9,823  
- Eni   2,643     2,328     2,857     5,771     7,751     4,593     5,585     7,059     8,788     9,217  
- Minority interest   80     142     140     251     468     629     569     482     459     606  
                                                             
Eni’s profit   2,643     2,328     2,857     5,771     7,751     4,593     5,585     7,059     8,788     9,217  
Exclusion of inventory holding (gains) loss                                             (281 )   (759 )   33  
Exclusion of special items:                           (1,994 )   330     (489 )   (133 )   1,222     1,162  
- non-recurring (income) charges                                             5     290     239  
- other special charges                                             (138 )   932     923  
Eni’s adjusted net profit                           5,757     4,923     5,096     6,645     9,251     10,412  

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ENI FACT BOOK / FINANCIAL DATA

   Balance sheet (at December 31)  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Fixed assets                                                            
Property, plant and equipment, net   20,641     20,871     23,074     26,797     33,851     33,693     36,360     40,586     45,013     44,312  
Other tangible assets                                                         629  
Compulsory stock                                             1,386     2,194     1,827  
Intangible assets, net   1,689     1,776     2,175     2,391     2,850     3,175     3,610     3,313     3,194     3,753  
Investments   1,482     1,382     1,446     4,223     2,740     2,797     3,160     3,685     4,311     4,246  
Accounts receivable financing and securities related to operations   1,352     1,453     1,670     1,659     1,630     1,408     983     695     775     557  
Net accounts payable in relation to investments   (738 )   (746 )   (717 )   (825 )   (657 )   (870 )   (1,018 )   (888 )   (1,196 )   (1,090 )
    24,426     24,736     27,648     34,245     40,414     40,203     43,095     48,777     54,291     54,234  
Net working capital                                                            
Inventories   2,629     2,442     2,626     3,120     3,014     3,200     3,293     2,847     3,563     4,752  
Trade accounts receivable   6,448     6,076     7,486     9,186     9,346     9,090     9,772     10,525     14,101     15,230  
Trade accounts payable   (3,508 )   (3,517 )   (4,200 )   (4,903 )   (5,081 )   (5,579 )   (5,950 )   (5,837 )   (8,170 )   (10,528 )
Tax liabilities   (3,704 )   (3,083 )   (4,219 )   (5,629 )   (4,173 )   (2,978 )   (2,532 )   (3,056 )   (4,857 )   (5,396 )
Reserve for contingencies   (3,106 )   (3,246 )   (3,735 )   (5,702 )   (5,377 )   (5,522 )   (5,708 )   (5,736 )   (7,679 )   (8,614 )
Other operating assets (liabilities)   1,614     1,408     821     (602 )   1,636     1,585     446     (555 )   (526 )   (641 )
    373     80     (1,221 )   (1,973 )   (635 )   (204 )   (679 )   (1,812 )   (3,568 )   (5,197 )
Employee termination indemnitiesand other benefits   (505 )   (356 )   (411 )   (457 )   (486 )   (507 )   (555 )   (982 )   (1,031 )   (1,071 )
Capital employed, net   24,294     24,460     26,016     31,815     39,293     39,492     41,861     45,983     49,692     47,966  
Shareholders’ equity (1)   15,324     16,156     18,398     22,401     27,483     26,257     26,696     32,374     36,868     39,029  
Minority interests   920     1,234     1,351     1,672     1,706     2,094     1,622     3,166     2,349     2,170  
    16,244     17,390     19,749     24,073     29,189     28,351     28,318     35,540     39,217     41,199  
Net borrowings   8,050     7,070     6,267     7,742     10,104     11,141     13,543     10,443     10,475     6,767  
Total liabilities and shareholders’ equity   24,294     24,460     26,016     31,815     39,293     39,492     41,861     45,983     49,692     47,966  
        
(1)    Net of own shares in portfolio.

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ENI FACT BOOK / FINANCIAL DATA

   Cash flow statement and change
   in net borrowings
 

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Net profit   2,723     2,470     2,997     6,022     8,220     5,222     6,154     7,541     9,247     9,823  
as adjusted:                                                            
- amortization and depreciation and other non-monetary items   4,056     4,468     3,869     4,307     4,841     5,682     5,493     5,092     6,518     5,753  
- net gains on disposal of assets   (185 )   (443 )   (60 )   (82 )   (170 )   (152 )   (35 )   (793 )   (220 )   (59 )
- dividends, interest, extraordinary income (expense) and income taxes   2,706     1,743     2,618     4,990     2,164     3,305     3,268     5,740     8,471     10,435  
Cash generated from operating profit before changes in working capital   9,300     8,238     9,424     15,237     15,055     14,057     14,880     17,580     24,016     25,952  
Changes in working capital related to operations   (268 )   785     (660 )   (1,592 )   (206 )   (510 )   (465 )   (909 )   (2,422 )   (1,024 )
Dividends received, taxes paid,interest and extraordinary income/expense (paid) received during the year   (2,517 )   (2,159 )   (516 )   (3,062 )   (6,765 )   (2,969 )   (3,588 )   (4,171 )   (6,658 )   (7,927 )
Net cash provided by operating activities   6,515     6,864     8,248     10,583     8,084     10,578     10,827     12,500     14,936     17,001  
Capital expenditure   (4,169 )   (5,152 )   (5,483 )   (5,431 )   (6,606 )   (8,048 )   (8,802 )   (7,499 )   (7,414 )   (7,833 )
Acquisitions/investment in associates   (153 )   (407 )   (114 )   (3,483 )   (3,082 )   (1,315 )   (985 )   (316 )   (127 )   (95 )
Disposals   363     371     295     277     2,114     935     650     1,547     542     328  
Other cash flow related to capital expenditure, investments and disposals   (9 )   (118 )   (446 )   (69 )   (40 )   (319 )   1,110     97     293     361  
Free cash flow   2,547     1,558     2,500     1,877     470     1,831     2,800     6,329     8,230     9,762  
Borrowings (repayment) of debt related to financing activities   66     2,019     (433 )   111     994     (1,171 )   1,400     211     (109 )   216  
Changes in short and long-term finance debt   (1,121 )   (3,715 )   (294 )   121     (490 )   3,736     1,629     (3,743 )   (540 )   (682 )
Dividends paid and changes in minority interests and reserves   (999 )   (645 )   (1,311 )   (2,118 )   (950 )   (3,846 )   (5,933 )   (3,175 )   (7,284 )   (6,443 )
Change in consolidation area and exchange differences   67     (24 )   (29 )   41     38     (64 )   (107 )   (55 )   33     (201 )
NET CASH FLOW FOR THE PERIOD   560     (807 )   433     32     62     486     (211     (433 )   330     2,652  
                                                             
Free cash flow   2,547     1,558     2,500     1,877     470     1,831     2,800     6,329     8,230     9,762  
Net borrowings of acquired companies   1     (6 )         (901 )   (1,582 )   (51 )   (692 )         (19 )      
Net borrowings of divested companies   174     30     3     20     185     39     1     190     21     1  
Exchange differences on net borrowings and other changes   (213 )   43     (389 )   (353 )   (312 )   990     1,422     (64     (980 )   388  
Dividends paid and changes in minority interests and reserves   (999 )   (645 )   (1,311 )   (2,118 )   (950 )   (3,846 )   (5,933 )   (3,175 )   (7,284 )   (6,443 )
CHANGE IN NET BORROWINGS   1,510     980     803     (1,475 )   (2,189 )   (1,037 )   (2,402 )   3,280     (32 )   3,708  

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ENI FACT BOOK / FINANCIAL DATA

   Net sales from operations  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exploration & Production   6,897     5,206     6,840     12,308     13,960     12,877     12,746     15,346     22,531     27,173  
Gas & Power   9,985     9,625     9,900     14,427     16,098     15,297     16,067     17,302     22,969     28,368  
Refining & Marketing   11,834     10,374     14,415     25,462     22,083     21,546     22,148     26,089     33,732     38,210  
Petrochemicals   4,985     4,048     4,096     6,018     5,108     4,516     4,487     5,331     6,255     6,823  
Engineering & Construction   2,890     3,348     2,988     2,146     3,114     4,546     6,306     5,696     5,733     6,979  
Other activities   417     552     555     608     695     1,449     1,178     1,279     863     823  
Corporate and financial companies                                 586     700     851     1,239     1,174  
Activities to be divested   464     253     83                                            
Consolidation adjustment   (6,113 )   (5,065 )   (7,869 )   (13,031 )   (11,786 )   (12,895 )   (12,145 )   (14,349 )   (19,594 )   (23,445 )
    31,359     28,341     31,008     47,938     49,272     47,922     51,487     57,545     73,728     86,105  

 

   Net sales to customers  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exploration & Production   3,254     2,300     1,228     2,924     5,530     4,082     4,278     5,130     7,770     8,728  
Gas & Power   9,563     9,272     9,532     13,714     15,430     14,674     15,617     16,809     22,397     27,617  
Refining & Marketing   10,861     9,626     13,542     23,913     20,881     20,509     21,527     25,336     32,640     36,910  
Petrochemicals   4,640     3,787     3,777     5,448     4,637     3,770     4,049     4,832     5,572     6,156  
Engineering & Construction   2,450     2,938     2,689     1,762     2,605     4,067     5,409     4,793     4,808     6,208  
Other activities   129     166     157     177     89     701     445     525     317     303  
Corporate and financial companies                           100     119     162     120     224     183  
Activities to be divested   462     252     83                                            
    31,359     28,341     31,008     47,938     49,272     47,922     51,487     57,545     73,728     86,105  

 

   Net sales by geographic
   area of destination
 

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Italy   19,914     18,059     18,813     27,184     27,591     23,797     25,491     27,100     32,846     36,343  
Other EU countries   4,182     3,339     4,191     6,944     8,226     8,974     10,785     13,095     19,601     23,949  
Rest of Europe   1,785     1,737     1,551     2,711     3,136     4,188     3,303     3,769     5,123     6,975  
Africa   1,167     1,160     1,496     2,083     2,180     2,478     5,854     4,148     5,259     5,949  
Americas   2,334     2,432     3,148     6,034     6,169     5,317     2,778     5,790     6,103     6,250  
Asia   1,958     1,596     1,795     2,959     1,949     3,154     3,245     3,088     4,399     5,595  
Other areas   19     18     14     23     21     14     31     555     397     1,044  
Total outside Italy   11,445     10,282     12,195     20,754     21,681     24,125     25,996     30,445     40,882     49,762  
    31,359     28,341     31,008     47,938     49,272     47,922     51,487     57,545     73,728     86,105  

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Contents

ENI FACT BOOK / FINANCIAL DATA

   Purchases, services and other  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Production costs - raw, ancillary and consumable material   13,415     11,038     13,189     23,691     23,993     22,658     24,087     27,010     35,318     44,661  
Production costs - services   5,330     6,173     6,035     6,513     7,507     8,614     10,431     9,148     9,405     10,015  
Lease, rental and royalty expenses   1,155     1,048     941     1,203     1,242     1,454     1,407     1,609     1,929     1,903  
Net provisions to reserves for contingencies                                             553     1,643     767  
Other expenses   1,239     1,232     1,022     1,581     1,302     1,575     1,423     1,066     1,100     1,089  
less:                                                            
capitalized direct costs associated with self-constructed assets   (716 )   (805 )   (563 )   (616 )   (745 )   (842 )   (1,277 )   (1,039 )   (828 )   (945 )
services billed to joint venture partners   (612 )   (653 )   (624 )   (867 )   (1,189 )   (1,566 )   (1,505 )                  
    19,811     18,033     20,000     31,442     32,110     31,893     34,566     38,347     48,567     57,490  

 

   Payroll and related costs  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Wages and salaries   2,226     2,234     2,134     2,175     2,271     2,441     2,412     2,402     2,484     2,630  
Social security contributions   725     651     621     627     602     650     693     658     662     691  
Contributions to defined benefit plans   145     137     137     128     126     136     157     118     126     230  
Other costs   147     85     73     57     83     119     91     218     255     305  
less:                                                            
revenues related to personnel costs   (39 )   (36 )   (33 )   (40 )   (51 )   (53 )   (26 )                  
capitalized direct costs associated with self-constructed assets   (153 )   (154 )   (150 )   (161 )   (180 )   (190 )   (161 )   (151     (176 )   (206 )
    3,051     2,917     2,782     2,786     2,851     3,103     3,166     3,245     3,351     3,650  

 

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Contents

ENI FACT BOOK / FINANCIAL DATA

   Depreciation, amortization
   and impairments
 

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exploration & Production   1,810     1,897     1,654     2,364     3,163     3,552     3,133     3,047     3,945     4,646  
Gas & Power   994     1,033     1,045     474     500     417     533     637     684     687  
Refining & Marketing   420     459     476     502     508     490     493     465     462     434  
Petrochemicals   259     251     284     273     323     125     125     114     118     124  
Engineering & Construction   87     107     109     144     203     267     271     184     176     195  
Other activities   30     30     24     31     46     48     51     45     16     6  
Corporate and financial companies                                 63     104     106     112     70  
Activities to be divested   10     1                                                  
Unrealized profit in inventory                                                   (4 )   (9 )
Total depreciation and amortization   3,610     3,778     3,592     3,788     4,743     4,962     4,710     4,598     5,509     6,153  
Impairments   158     530     106     55     100     542     441     333     272     268  
    3,768     4,308     3,698     3,843     4,843     5,504     5,151     4,931     5,781     6,421  

 

 

   Operating profit by division  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exploration & Production   2,590     594     2,834     6,603     5,984     5,175     5,746     8,185     12,592     15,580  
Gas & Power   2,012     2,513     2,580     3,178     3,672     3,244     3,627     3,428     3,321     3,802  
Refining & Marketing   578     730     478     986     985     321     583     1,080     1,857     319  
Petrochemicals   187           (362 )   4     (415 )   (126 )   (176 )   320     202     172  
Engineering & Construction   169     198     149     144     255     298     311     203     307     505  
Other activities                                 (214 )   (293 )   (395 )   (934 )   (622 )
Corporate and financial companies   (138 )   (168 )   (199 )   (143 )   (168 )   (196 )   (281 )   (363 )   (377 )   (296 )
Activities to be divested   (53 )   (57 )                                                
Unrealized profit in inventory (1)                                             (59 )   (141 )   (133 )
    5,345     3,810     5,480     10,772     10,313     8,502     9,517     12,399     16,827     19,327  
     
(1)   Unrealized profit in inventory concerned intersegment sales of goods and services recorded within assets of the purchasing division as of end of the period.

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Contents

ENI FACT BOOK / FINANCIAL DATA

RECONCILIATION OF REPORTED OPERATING PROFIT
AND NET PROFIT TO RESULTS ON AN ADJUSTED BASIS

Management evaluates Group and business performance on the basis of adjusted operating profit and adjusted net profit, which are arrived at by excluding inventory holding gains or losses and special items. Further, finance charges on finance debt, interest income, charges or income deriving from the fair value evaluation of derivative financial instruments held for trading purposes, and exchange rate differences are excluded when determining adjusted net profit of each business segment.

Taxation effect of such items excluded from adjusted net profit is determined based on the specific rate of taxes applicable to each item, with the exception of finance charges or income, to which the Italian statutory tax rate of 33% is applied.

Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or U.S. GAAP. Management includes them to facilitate comparison of base business performance across periods and allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models. In addition, management uses segmental adjusted net profit when calculating return on average capital employed (ROACE) by each business segment.

The following is a description of items which are excluded from the calculation of adjusted results.

Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold in the period calculated using the weighted-average cost method of inventory accounting.

Special items include certain relevant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-
  recurring items under such circumstances; or (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past exercises or are likely to occur in future ones.
As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. In addition the effect of the fair value evaluation of derivative financial instruments held for trading purposes and exchange rate differences are excluded from the adjusted net profit of business segments. Therefore, the adjusted net profit of business segments includes finance charges or income deriving from certain segment-operated assets, i.e., interest income on certain receivable financing and securities related to operations and finance charges pertaining to the accretion of certain provisions recorded on a discounted basis (as in the case of asset retirement obligations in the Exploration and Production division).

Finance charges or interest income and related taxation effects, excluded from the adjusted net profit of the business segments are allocated on the aggregate Corporate and financial companies.

For a reconciliation of adjusted operating profit and adjusted net profit to reported operating profit and net profit see tables below.

 

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Contents

ENI FACT BOOK / FINANCIAL DATA

  2001

Italian GAAP  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit  

5,984

   

3,672

   

985

   

(415

)  

255

   

(168

)              

10,313

 
Exclusion special items:                                                      
- impairments  

88

   

3

   

9

   

100

                           

200

 
- gain from decrease in inventory              

   

      (31 )                          

(31

)
Special items of operating profit  

88

   

3

   

9

     

69

                           

169

 
Adjusted operating profit  

6,072

   

3,675

   

994

   

(346

)  

255

   

(168

)              

10,482

 
Eni's net profit                                                  

7,751

 
Exclusion special items:                                                  

(1,994

)
Eni's adjusted net profit                                                  

5,757

 

 

  2002

Italian GAAP  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit  

5,175

   

3,244

   

321

   

(126

)  

298

   

(214

)  

(196

)        

8,502

 
Exclusion special items:                                                      
- impairments  

332

   

95

   

4

   

105

         

6

               

542

 
- environmental tax Sicilia Region        

86

                                       

86

 
- gains on disposal of assets  

(92

)                                            

(92

)
- inventory holding (gains) losses              

(13

)  

(27

)                          

(40

)
- (costs) gains from preceding years  

13

   

(74

)                                      

(61

)
- other        

22

                                       

22

 
Special items of operating profit  

253

   

129

   

(9

)  

78

         

6

               

457

 
Adjusted operating profit  

5,428

   

3,373

   

312

   

(48

)  

298

   

(208

)  

(196

)        

8,959

 
Eni's net profit                                                  

4,593

 
Exclusion special items                                                  

330

 
Eni's djusted net profit                                                  

4,923

 

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Contents

ENI FACT BOOK / FINANCIAL DATA

  2003

Italian GAAP  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit  

5,746

   

3,627

   

583

   

(176

)  

311

   

(293

)  

(281

)        

9,517

 
Exclusion special items of operating profit:                                                      
- impairments  

227

   

34

   

1

   

122

         

57

               

441

 
Special items of operating profit  

227

   

34

   

1

   

122

   

  

   

57

   

  

   

  

   

441

 
Adjusted operating profit  

5,973

   

3,661

   

584

   

(54

)  

311

   

(236

)  

(281

)  

  

   

9,958

 
Eni's net profit                                                  

5,585

 
Exclusion special items                                                  

(489

)
Adjusted net profit                                                  

5,096

 

 

  2004

IFRS  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit   8,185     3,428     1,080     320     203     (395 )   (346 )   (59 )   12,399  
Exclusion of inventory holdings (gains) losses         (12 )   (393 )   (43 )                           (448 )
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income)         5                                         5  
Other special charges:   17     27     236     (14 )   12     172     176           626  
- environmental charges         5     142                 84     72           303  
- assets impairments   287     6     21     3           19                 336  
- gains on disposal of assets   (320 )                                             (320 )
- provisions to the reserve for contingencies   29     18     77     3     1     15                 143  
- increase insurance charges                                       91           91  
- provision for redundancy incentives   2     10     20     6     10     6     11           65  
- other   19     (12 )   (24 )   (26 )   1     48     2           8  
Special items of operating profit   17     32     236     (14 )   12     172     176           631  
Adjusted operating profit   8,202     3,448     923     263     215     (223 )   (187 )   (59 )   12,582  
Net financial (expense) income (*)   (85 )   31     5                       (107 )         (156 )
Net income from investments (*)   9     215     96     2     118     4     (14 )         430  
Income taxes (*)   (4,093 )   (1,404 )   (350 )   (23 )   (81 )   (22 )   222     22     (5,729 )
Tax rate (%)   50.4     38.0     34.2                                   44.6  
Adjusted net profit   4,033     2,290     674     242     252     (241 )   (86 )   (37 )   7,127  
of which:                                                      
- net profit of minorities                                                   482  
- adjusted net profit pertaining to Eni                                                   6,645  
Reported net profit pertaining to Eni                                                   7,059  
Exclusion of inventory holding (gains) losses                                                   (281 )
Exclusion of special items                                                   (133 )
- non-recurring (income) charges                                                   5  
- other special charges                                                   (138 )
Adjusted net profit pertaining to Eni                                                   6,645  
     
(*)   Excludes special items.

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Contents

ENI FACT BOOK / FINANCIAL DATA

  2005

IFRS  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit   12,592     3,321     1,857     202     307     (934)     (377)     (141)     16,827  
Exclusion of inventory holding (gains) losses         (127 )   (1,064 )   (19 )                           (1,210 )
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges         290                                         290  
Other special charges:   311     47     421     78     7     638     149           1,651  
- environmental charges         31     337                 413     54           835  
- assets impairments   247     1     5     29     4     75     2           363  
- provisions to the reserve for contingencies               39     36           126                 201  
- increase insurance charges   57     6     30     17           4     64           178  
- provision for redundancy incentives   7     8     22     4     3     6     29           79  
- other         1     (12 )               14                 (5 )
Special items of operating profit   311     337     421     78     7     638     149           1,941  
Adjusted operating profit   12,903     3,531     1,214     261     314     (296 )   (228 )   (141 )   17,558  
Net financial (expense) income (*)   (80 )   37                             (296 )         (339 )
Net income from investments (*)   10     370     231     3     141     (1 )   23           777  
Income taxes (*)   (6,647 )   (1,386 )   (500 )   (37 )   (127 )         359     52     (8,286 )
Tax rate (%)   51.8     35.2     34.6                                   46.0  
Adjusted net profit   6,186     2,552     945     227     328     (297 )   (142 )   (89 )   9,710  
of which:                                                      
- net profit of minorities                                                   459  
- Eni’s adjusted net profit                                                   9,251  
Eni’s reported net profit                                                   8,788  
Exclusion of inventory holding (gains) losses                                                   (759 )
Exclusion of special items                                                   1,222  
- non-recurring (income) charges                                                   290  
- other special charges                                                   932  
Eni’s adjusted net profit                                                   9,251  
     
(*)   Excludes special items.

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Contents

ENI FACT BOOK / FINANCIAL DATA

  2006

IFRS  

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

Reported operating profit   15,580     3,802     319     172     505     (622 )   (296 )   (133 )   19,327  
Exclusion of inventory holding (gains) losses         (67 )   215     (60 )                           88  
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges         55     109     13           62                 239  
Other special charges:   183     92     147     94     3     261     56           836  
- environmental charges         44     111                 126     11           292  
- assets impairments   231     51     14     50     1     22                 369  
- gains on disposal of assets   (61 )                                             (61 )
- provisions to the reserve for contingencies               8     31           75                 114  
- provisions for redundancy incentives   13     37     47     19     2     17     43           178  
- other         (40 )   (33 )   (6 )         21     2           (56 )
Special items of operating profit   183     147     256     107     3     323     56           1,075  
Adjusted operating profit   15,763     3,882     790     219     508     (299 )   (240 )   (133 )   20,490  
Net financial (expense) income (*)   (59 )   16                       (7 )   205           155  
Net income from investments (*)   85     489     184     2     66     5                 831  
Income taxes (*)   (8,510 )   (1,525 )   (345 )   (47 )   (174 )         89     54     (10,458 )
Tax rate (%)   53.9     34.8     35.4                                   48.7  
Adjusted net profit   7,279     2,862     629     174     400     (301 )   54     (79 )   11,018  
of which:                                                      
- net profit of minorities                                                   606  
- Eni’s adjusted net profit                                                   10,412  
Eni’s reported net profit                                                   9,217  
Exclusion of inventory holding (gains) losses                                                   33  
Exclusion of special items                                                   1,162  
- non-recurring (income) charges                                                   239  
- other special charges                                                   923  
Eni’s adjusted net profit                                                   10,412  
     
(*)   Excludes special items.

- 97 -


Contents

ENI FACT BOOK / FINANCIAL DATA

   Adjusted operating profit by division  

Italian GAAP

 

IFRS

   
 
   (million euro)  

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Exploration & Production   6,072     5,428     5,973     8,202     12,903     15,763  
Gas & Power   3,675     3,373     3,661     3,448     3,531     3,882  
Refining & Marketing   963     312     584     923     1,214     790  
Petrochemicals   (315 )   (48 )   (54 )   263     261     219  
Engineering & Construction   255     298     311     215     314     508  
Other activities         (208 )   (236 )   (223 )   (296 )   (299 )
Corporate and financial companies   (168 )   (196 )   (281 )   (187 )   (228 )   (240 )
Unrealized profit in inventory                     (59 )   (141 )   (133 )
    10,482     8,959     9,958     12,582     17,558     20,490  

 

  Adjusted net profit by division              

2004

 

2005

 

2006

 (million euro)                                    
Exploration & Production                     4,033     6,186     7,279  
Gas & Power                     2,290     2,552     2,862  
Refining & Marketing                     674     945     629  
Petrochemicals                     242     227     174  
Engineering & Construction                     252     328     400  
Other activities                     (241 )   (297 )   (301 )
Corporate and financial companies                     (86 )   (142 )   54  
Unrealized profit in inventory                     (37 )   (89 )   (79 )
                      6,645     9,251     10,412  

 

  Analysis of special items  

2001

 

2002

 

2003

 

2004

 

2005

 

2006

 (million euro)                                    
Non recurring (income) charges                     5     290     239  
Other special charges:   169     457     441     626     1,651     836  
     environmental charges                     303     835     292  
     asset impairments   542     442     336     363     369        
     gains on disposal of assets         (92 )         (320 )         (61 )
     provisions to the reserve for contingencies                     234     379     114  
          of which:                                    
          increase insurance charges                           178        
          provision for redundancy incentives                     65     79     178  
          other   (31 )   7           8     (5 )   (56 )
Special items of operating profit   169     457     441     631     1,941     1,075  
Net financial (expense) income                           27     (6 )
Net income from investments   82     36           (390 )   (137 )   (72 )
     of which:                                    
     gain on the disposal of Italiana Petroli (IP)                           (132 )      
     gain on Galp Energia SGPS SA (disposal assets Rede Electrica National)                           (73 )      
     gain on the disposal of shares of Snam Rete Gas SpA                     (308 )            
Income taxes   (1,737 )   29     (49 )                  
     of which:                                    
     supplemental tax rate UK                                 91  
     windfall tax Algeria                                 179  
     legal proceeding in Venezuela                                 77  
Total special items of net profit   (1,994 )   330     (489 )   (133 )   1,222     1,162  

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Contents

ENI FACT BOOK / FINANCIAL DATA

   Net financial (expense) income  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exchange gain (loss), net   33     49     (27 )   165     (10 )   (30 )               169     (152 )
Interest and other net financial income   579     485     339     501     539     512     436     2     74     215  
Securities gains   246     176     197     116     95     44     34     31     36     51  
Interest and other financial expense   (1,125 )   (790 )   (556 )   (791 )   (978 )   (738 )   (710 )   (316 )   (309 )   (336 )
Financial expense due to the passage of time                                             (109 )   (109 )   (116 )
Income (expense) on derivatives                                             34     (386 )   383  
less:                                                            
interest capitalized   38     39     57     73     49     43     86     202     159     116  
    (262 )   (41 )   10     64     (305 )   (169 )   (154 )   (156 )   (366 )   161  
of which income on receivables related to operations and tax credits   197     195     254     201     170     122     116     91     99     114  

 

   Income (expense on) from investments  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Income from equity investments   91     68     108     147     158     184     189     401     770     887  
Writedown of investments   (213 )   (143 )   (101 )   (178 )   (282 )   (245 )   (278 )   (69 )   (33 )   (36 )
Gains on sales   135     401     17     19     76     55     39     130     179     25  
Losses on sales                                             (1 )   (8 )   (7 )
Dividends   42     67     63     44     40     32     22     72     33     98  
Provision for losses                                                         (56 )
Other income (expense) net   4     3     2     1     1     17     11     287     (27 )   (8 )
    59     396     89     33     (7 )   43     (17 )   820     914     903  

 

   Fixed assets (at period end)  

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Fixed assets, gross                                                            
Exploration & Production   17,633     18,878     23,329     28,220     38,667     38,534     38,811     40,322     49,129     49,002  
Gas & Power   14,513     14,997     15,579     16,881     15,867     16,467     18,926     20,680     21,517     22,277  
Refining & Marketing   7,852     8,316     8,620     8,854     9,083     8,172     8,652     8,947     9,420     11,273  
Petrochemicals   4,163     4,356     4,611     4,618     5,862     4,169     4,266     4,311     4,402     4,380  
Engineering & Construction   1,614     1,898     2,336     2,564     2,805     3,447     3,531     3,524     3,878     4,363  
Other activities   227     239     202     224     241     2,472     2,403     2,300     1,999     1,967  
Corporate and financial companies                                 132     149     194     453     321  
Activities to be divested   424     340                                                  
Unrealized profit in inventory                                                   (88 )   (128 )
    46,426     49,024     54,677     61,361     72,525     73,393     76,738     80,278     90,710     93,455  
Fixed assets, net                                                            
Exploration & Production   7,651     7,790     10,155     13,113     20,728     19,862     20,338     20,761     24,485     23,002  
Gas & Power   6,624     6,419     6,142     7,068     6,598     7,191     9,500     13,235     13,760     14,067  
Refining & Marketing   3,409     3,566     3,472     3,393     3,332     3,097     3,170     3,361     3,556     3,791  
Petrochemicals   2,076     2,071     1,958     1,759     1,626     1,285     1,181     1,181     1,139     1,072  
Engineering & Construction   718     919     1,257     1,370     1,467     1,758     1,741     1,646     1,847     2,225  
Other activities   97     104     90     94     100     418     338     293     117     93  
Corporate and financial companies                                 82     92     109     193     176  
Activities to be divested   66     2                                                  
Unrealized profit in inventory                                                   (84 )   (114 )
    20,641     20,871     23,074     26,797     33,851     33,693     36,360     40,586     45,013     44,312  

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Contents

ENI FACT BOOK / FINANCIAL DATA

   Capital expenditure by division   

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Exploration & Production   2,322     2,882     3,268     3,539     4,276     5,615     5,681     4,853     4,965     5,203  
Gas & Power   882     921     906     794     1,065     1,315     1,760     1,451     1,152     1,174  
Refining & Marketing   495     586     524     533     496     550     730     693     656     645  
Petrochemicals   180     331     289     265     390     145     141     148     112     99  
Engineering & Construction   237     354     425     245     304     233     278     186     349     591  
Other activities   34     61     55     55     75     119     70     49     48     72  
Corporate and financial companies                                 71     142     119     132     88  
Activities to be divested   19     17     16                                         (39 )
    4,169     5,152     5,483     5,431     6,606     8,048     8,802     7,499     7,414     7,833  

 

   Capital expenditure by
   geographic area of origin
 

Italian GAAP

 

IFRS

   
 
  (million euro)

    

    

1997

   

1998

   

1999

   

2000

   

2001

   

2002

   

2003

   

2004

   

2005

   

2006

Italy   2,246     2,535     2,238     2,206     2,436     2,396     2,708     2,655     2,442     2,529  
Other European Union countries   478     439     320     439     595     567     1,067     337     545     713  
Rest of Europe   306     465     390     283     249     284     302     387     415     436  
Africa   904     1,103     1,159     1,186     1,405     2,497     3,026     2,622     2,233     2,419  
Americas   144     261     1,095     753     923     721     369     357     507     572  
Asia   90     345     280     562     923     1,333     795     1,066     1,181     1,032  
Other areas   1     4     1     2     75     250     535     75     91     132  
Total outside Italy   1,923     2,617     3,245     3,225     4,170     5,652     6,094     4,844     4,972     5,304  
    4,169     5,152     5,483     5,431     6,606     8,048     8,802     7,499     7,414     7,833  

 

   Investments  

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                                 
Total investments       4,384   4,664   1,366   4,255   316   146   95
Lasmo Plc   100%   1,225   4,128                    
British-Borneo   100%   1,263                        
Galp   33.34%   964                        
Natural gas distribution company in Argentina   minority stake   216                        
Natural gas distribution company in Greece   minority stake   192                        
Polimeri Europa SpA   50%       204                    
Bouygues Offshore   100%           906                
GVS (1)   50%           352                
Italgas SpA   56%               2,569            
Fortum Petroleum   100%               909            
Unión Fenosa Gas SA   50%               442            
Natural gas distribution company in Italy   minority stake                   44   6   46
Natural gas production company in Italy   100%                       91    
     
(1)   Of this euro 89 million paid by Eni and euro 263 million through net borrowings of non-consolidated subsidiaries.

- 100 -


Contents

ENI FACT BOOK / FINANCIAL DATA

Net borrowings
(at period end)

(million euro)

 

Debt and bonds

 

Cash

 

Securities not related to operations

 

Accounts receivable financing not related to operations

 

Other, net

 

Total

1997                                    
Short-term  

7,924

   

(1,586

)  

(2,204

)  

(1,180

)  

(5

)  

2,949

 
Long-term  

5,347

         

(156

)  

(91

)  

1

   

5,101

 
   

13,271

   

(1,586

)  

(2,360

)  

(1,271

)  

(4

)  

8,050

 
1998                                    
Short-term  

4,948

   

(779

)  

(1,119

)  

(389

)  

(6

)  

2,655

 
Long-term  

4,517

         

(85

)        

(17

)  

4,415

 
   

9,465

   

(779

)  

(1,204

)  

(389

)  

(23

)  

7,070

 
1999                                    
Short-term  

4,764

   

(1,212

)  

(1,645

)  

(343

)  

26

   

1,590

 
Long-term  

4,787

         

(85

)        

(25

)  

4,677

 
   

9,551

   

(1,212

)  

(1,730

)  

(343

)  

1

   

6,267

 
2000                                    
Short-term  

5,928

   

(1,244

)  

(1,432

)  

(550

)  

(50

)  

2,652

 
Long-term  

5,116

         

(24

)        

(2

)  

5,090

 
   

11,044

   

(1,244

)  

(1,456

)  

(550

)  

(52

)  

7,742

 
2001                                    
Short-term  

6,464

   

(1,305

)  

(940

)  

(74

)  

(29

)  

4,116

 
Long-term  

6,084

         

(312

)              

5,772

 
   

12,819

   

(1,360

)  

(1,252

)  

(74

)  

(29

)  

10,104

 
2002                                    
Short-term  

8,870

   

(1,791

)  

(730

)  

(1,465

)  

(3

)  

4,881

 
Long-term  

6,550

         

(290

)              

6,260

 
   

15,420

   

(1,791

)  

(1,020

)  

(1,465

)  

(3

)  

11,141

 
2003                                    
Short-term  

7,918

   

(1,580

)  

(792

)  

(32

)  

(65

)  

5,449

 
Long-term  

8,336

         

(2

)  

(240

)        

8,094

 
   

16,254

   

(1,580

)  

(794

)  

(272

)  

(65

)  

13,543

 
2004                                    
Short-term  

5,077

   

(1,003

)  

(792

)  

(11

)  

(194

)  

3,077

 
Long-term  

7,607

         

(1

)  

(240

)        

7,366

 
   

12,684

   

(1,003

)  

(793

)  

(251

)  

(194

)  

10,443

 
2005                                    
Short-term  

5,345

   

(1,333

)  

(903

)  

(12

)        

3,097

 
Long-term  

7,653

         

(28

)  

(247

)        

7,378

 
   

12,998

   

(1,333

)  

(931

)  

(259

)        

10,475

 
2006                                    
Short-term   4,324     (3,985 )   (552 )   (143 )         (356 )
Long-term   7,375                 (252 )         7,123  
    11,699     (3,985 )   (552 )   (395 )         6,767  

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Contents

ENI FACT BOOK / EMPLOYEES

Employees

   Number of employees at year end  

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

(units)                                            
Exploration & Production   Italy   5,912   5,444   5,294   5,014   4,495   4,617   4,555   4,539   5,027   5,273
    Outside Italy   2,666   2,726   2,479   2,727   3,038   3,098   2,937   2,938   3,003   3,063
        8,578   8,170   7,773   7,741   7,533   7,715   7,492   7,477   8,030   8,336
Gas & Power   Italy   14,474   13,977   13,669   13,175   11,704   10,852   10,302   10,216   9,733   9,602
    Outside Italy   3,432   3,132   2,806   2,925   2,582   2,465   2,680   2,627   2,591   2,472
        17,906   17,109   16,475   16,100   14,286   13,317   12,982   12,843   12,324   12,074
Refining & Marketing   Italy   11,543   11,176   10,341   9,760   8,638   7,332   6,882   6,879   6,680   7,196
    Outside Italy   6,897   7,230   6,720   6,370   6,534   6,425   6,395   2,345   2,214   2,241
        18,440   18,406   17,061   16,130   15,172   13,757   13,277   9,224   8,894   9,437
Petrochemicals   Italy   14,354   12,957   12,596   11,573   10,910   5,744   5,585   5,237   5,164   4,948
    Outside Italy   1,653   1,370   1,312   1,284   1,569   1,514   1,465   1,328   1,298   1,077
        16,007   14,327   13,908   12,857   12,479   7,258   7,050   6,565   6,462   6,025
Engineering & Construction                                            
     Oilfield Services
     and Construction
  Italy   2,925   2,832   2,648   2,326   2,279   2,255   2,423   2,490   5,799   6,164
    Outside Italy   8,086   9,682   7,359   7,560   12,881   22,770   18,036   18,890   22,885   24,738
        11,011   12,514   10,007   9,886   15,160   25,025   20,459   21,380   28,684   30,902
     Engineering   Italy   3,402   3,376   3,328   3,102   3,001   3,055   3,433   3,544        
    Outside Italy   411   393   378   330   417   633   1,580   1,349        
        3,787   3,721   3,480   3,331   3,472   4,066   5,124   4,439        
Other activities   Italy   2,834   3,527   3,247   3,841   4,255   6,347   6,367   4,959   2,636   2,219
    Outside Italy   94   69   72   83   48   13   13   24        
        2,928   3,596   3,319   3,924   4,303   6,360   6,380   4,983   2,636   2,219
Corporate and financial companies   Italy                       3,107   2,577   3,351   5,153   4,363
    Outside Italy                       50   80   86   75   216
                            3,157   2,657   3,437   5,228   4,579
Activities to be divested   Italy   1,521   1,063                                
    Outside Italy                                        
        1,521   1,063                                
Total employees at year end   Italy   56,939   54,304   50,897   48,690   45,336   43,687   42,235   40,761   40,192   39,765
    Outside Italy   23,239   24,602   21,126   21,279   27,069   36,968   33,186   29,587   32,066   33,807
        80,178   78,906   72,023   69,969   72,405   80,655   75,421   70,348   72,258   73,572
of which senior managers       1,992   1,941   1,788   1,683   1,438   1,537   1,733   1,764   1,748   1,604

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Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Supplemental oil and gas information

OIL AND NATURAL GAS RESERVES
Proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under technical, contractual, economic and operating conditions existing at the time. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. Net proved reserves exclude royalties and interests owned by others. Proved developed oil and gas reserves are proved reserves that can be estimated to be recovered through existing wells with existing equipment and operating methods.Proved undeveloped oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for completion. Additional oil and gas reserves expected to be obtained through the application of fluid injection or other improved recovery techniques for supplementing natural forces and mechanisms of primary recovery are included as proved developed reserves only after testing by a pilot project or after the operation of an installed program has confirmed, through production response, that increased recovery will be achieved. Eni’s proved reserves have been estimated on the basis of the applicable U.S. Securities & Exchange Commission regulation, Rule 4-10 of Regulation S-X and its interpretations and have been disclosed in accordance with Statement of Financial Accounting Standard No. 69.
The estimates of proved reserves, developed and undeveloped for years ended December 31, 2003, 2004, 2005 and 2006 are based on data prepared by Eni. Since 1991, Eni has requested qualified independent oil engineering companies carry out an independent evaluation1 of its proved reserves on a rotational basis. In particular a total of 1.4 billion boe of proved reserves, or about 21% of Eni’s total proved reserves at December 31, 2006, have been evaluated. The results of this independent evaluation confirmed Eni’s evaluations, as in previous years. In the 2004-2006 three-year period, 76% of Eni’s total proved reserves were subject to independent evaluations. Eni operates under Production Sharing Agreements, (PSAs), in several of the foreign jurisdictions where it has oil and gas exploration and production activities. Reserves of oil and natural gas to which Eni is entitled under PSA arrangements are shown in accordance with Eni’s economic interest in the volumes of oil and natural gas estimated to be recoverable
  in future years. Such reserves include estimated quantities allocated to Eni for recovery of costs, income taxes owed by Eni but settled by its joint venture partners (which are state-owned entities) out of Eni’s share of production and Eni’s net equity share after cost recovery. Proved oil and gas reserves associated with PSAs represented 51%, 48% and 53% of total proved reserves as of year-end 2004, 2005 and 2006, respectively, on an oil-equivalent basis. A similar scheme to PSAs applies to Service and “Buy-Back” contracts; proved reserves associated with such contracts represented 3%, 2% and 2% of total proved reserves on an oil-equivalent basis as of year-end 2004, 2005 and 2006, respectively.
Oil and gas reserve quantities include: (i) oil and natural gas quantities in excess to cost recovery which the company has an obligation to purchase under certain PSAs with governments or authorities whereby the company serves as producer of reserves. In accordance with SFAS No. 69, paragraph 13, reserve volumes associated with such oil and gas quantities represented 1.4%, 1.7% and 1.1% of total proved reserves as of year-end 2004, 2005 and 2006 respectively, on an oil-equivalent basis; (ii) volumes of natural gas used for own consumption and (iii) volumes of natural gas held in certain Eni storage fields in Italy. Proved reserves attributable to these fields include: (a) the residual natural gas volumes of the reservoirs and (b) natural gas volumes from other Eni fields input into these reservoirs in subsequent periods. Proved reserves do not include volumes owned by or acquired from third parties.
Gas withdrawn from storage is produced and thereby detracted from proved reserves when sold. Numerous uncertainties are inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures. The accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Results of drilling, testing and production after the date of the estimate may require substantial upward or downward revision. In addition, changes in oil and natural gas prices have an effect on the quantities of Eni’s proved reserves since estimates of reserves are based on prices and costs relative to the date when such estimates are made. Reserve estimates are also subject to revision as prices fluctuate due to the cost recovery feature under certain PSAs. The following table presents yearly changes by geographical area in estimated proved reserves, developed and undeveloped, of crude oil (including condensate and natural gas liquids) and natural gas for the years 2004, 2005 and 2006.

 

(1)   From 1991 to 2002 to DeGolyer and MacNaughton, from 2003 also to Ryder Scott Company.

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Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Proved hydrocarbon reserves (1)
(mmboe)  

Italy (2)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Proved reserves of subsidiaries

 

Proved reserves of affiliates and joint ventures

 

Total

Reserves at December 31, 1996  

1,637

   

1,420

   

847

   

643

   

128

               

4,675

 
Purchase of minerals in place  

37

   

1

               

254

               

292

 
Revisions of previous estimates  

31

   

77

   

46

   

24

   

25

               

203

 
Improved recovery        

1

   

2

   

14

                     

17

 
Extensions and discoveries  

83

   

117

   

24

   

44

   

5

               

273

 
Production  

(142

)  

(85

)  

(67

)  

(59

)  

(20

)              

(373

)
Sales of minerals in place        

(1

)        

(11

)  

(2

)              

(14

)
Reserves at December 31, 1997  

1,646

   

1,530

   

852

   

655

   

390

               

5,073

 
Purchase of minerals in place                                                
Revisions of previous estimates  

13

   

126

   

65

   

41

   

(24

)              

221

 
Improved recovery              

17

                           

17

 
Extensions and discoveries  

68

   

118

   

49

   

27

   

73

               

335

 
Production  

(153

)  

(88

)  

(73

)  

(57

)  

(20

)              

(391

)
Sales of minerals in place                                                
Reserves at December 31, 1998  

1,574

   

1,686

   

910

   

666

   

419

               

5,255

 
Purchase of minerals in place  

6

   

17

         

5

   

93

               

121

 
Revisions of previous estimates  

24

   

208

   

48

   

28

   

(1

)              

307

 
Improved recovery              

3

                           

3

 
Extensions and discoveries  

11

   

37

   

180

   

1

   

14

               

243

 
Production  

(138

)  

(99

)  

(74

)  

(54

)  

(30

)              

(395

)
Sales of minerals in place                                                
Reserves at December 31, 1999  

1,477

   

1,849

   

1,067

   

646

   

495

               

5,534

 
Purchase of minerals in place        

3

   

12

   

80

   

159

               

254

 
Revisions of previous estimates  

15

   

86

   

56

   

32

   

231

               

419

 
Improved recovery        

3

   

9

                           

12

 
Extensions and discoveries  

16

   

100

   

32

   

3

   

69

               

220

 
Production  

(119

)  

(111

)  

(83

)  

(62

)  

(56

)              

(430

)
Sales of minerals in place        

(1

)                                

(1

)
Reserves at December 31, 2000  

1,389

   

1,929

   

1,093

   

700

   

897

               

6,008

 
Purchase of minerals in place  

3

   

118

         

206

   

437

               

764

 
Revisions of previous estimates  

22

   

171

   

93

   

63

   

166

               

515

 
Improved recovery        

11

   

16

   

6

                     

33

 
Extensions and discoveries  

21

   

8

   

24

   

9

   

58

               

120

 
Production  

(120

)  

(115

)  

(86

)  

(104

)  

(81

)              

(506

)
Sales of minerals in place              

(4

)  

(1

)                    

(5

)
Reserves at December 31, 2001  

1,315

   

2,122

   

1,136

   

879

   

1,477

               

6,929

 
Purchase of minerals in place                    

27

   

12

               

39

 
Revisions of previous estimates  

5

   

14

   

113

   

24

   

181

               

337

 
Improved recovery        

14

   

1

                           

15

 
Extensions and discoveries  

29

   

12

   

124

   

31

   

142

               

338

 
Production  

(111

)  

(129

)  

(87

)  

(112

)  

(93

)              

(532

)
Sales of minerals in place  

(39

)              

(24

)  

(33

)              

(96

)
Reserves at December 31, 2002  

1,199

   

2,033

   

1,287

   

825

   

1,686

               

7,030

 
Purchase of minerals in place  

2

               

159

   

1

               

162

 
Revisions of previous estimates  

(116

)  

29

   

89

   

77

   

208

               

287

 
Improved recovery        

15

   

16

                           

31

 
Extensions and discoveries  

22

   

74

   

27

         

232

               

355

 
Production  

(111

)  

(127

)  

(95

)  

(126

)  

(111

)              

(570

)
Sales of minerals in place                    

(23

)                    

(23

)

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Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Proved hydrocarbon reserves (1)
(mmboe)  

Italy (2)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Proved reserves of subsidiaries

 

Proved reserves of affiliates and joint ventures

 

Total

Reserves at December 31, 2003   996     2,024     1,324     911     2,017     7,272           7,272  
Revisions of previous estimates         127     69     29     2     227           227  
Improved recovery         11     50     4           65           65  
Extensions and discoveries   8     94     34     10     183     329           329  
Production   (101 )   (137 )   (116 )   (112 )   (128 )   (594 )         (594 )
Sales of minerals in place   (13 )   (2 )   (4 )   (36 )   (26 )   (81 )         (81 )
2004 reconciliation referring to reserves of affiliates and joint venture         (30 )   (9 )         (25 )   (64 )   64        
Reserves at December 31, 2004  

890

   

2,087

   

1,348

   

807

   

2,022

   

7,154

   

64

   

7,218

 
Purchase of minerals in place  

13

   

  

   

8

   

  

   

85

   

106

          

106

 
Revisions of previous estimates  

59

   

35

   

(48

)  

25

   

(151

)  

(80

)  

(18

)  

(98

)
Improved recovery  

  

   

44

   

30

   

  

   

15

   

89

          

89

 
Extensions and discoveries  

  

   

33

   

67

   

30

   

26

   

156

         

156

 
Production  

(94

)  

(173

)  

(126

)  

(104

)  

(132

)  

(629

)  

(5

)  

(634

)
Sales of minerals in place   

  

     

  

     

  

     

  

     

  

     

  

              

  

  
Reserves at December 31, 2005  

868

   

2,026

   

1,279

   

758

   

1,865

   

6,796

   

41

   

6,837

 
Purchase of minerals in place                     1           1           1  
Revisions of previous estimates   21     88     (79 )   28     92     151           151  
Improved recovery         49     41           14     104     1     105  
Extensions and discoveries   3     55     16           86     161           161  
Production   (87 )   (201 )   (135 )   (103 )   (114 )   (640 )   (6 )   (646 )
Sales of minerals in place                     (3 )   (170 )   (173 )         (173 )
Reserves at December 31, 2006   805     2,018     1,122     682     1,773     6,400     36     6,436  

 

Proved developed hydrocarbon reserves (1)
Reserves at December 31, 1996  

1,069

   

761

   

458

   

468

   

72

               

2,828

 
Reserves at December 31, 1997  

1,018

   

734

   

454

   

423

   

73

               

2,702

 
Reserves at December 31, 1998  

914

   

778

   

476

   

460

   

102

               

2,730

 
Reserves at December 31, 1999  

921

   

796

   

586

   

416

   

202

               

2,921

 
Reserves at December 31, 2000  

860

   

824

   

590

   

443

   

301

               

2,995

 
Reserves at December 31, 2001  

825

   

875

   

640

   

773

   

654

               

3,767

 
Reserves at December 31, 2002  

774

   

797

   

703

   

724

   

705

               

3,703

 
Reserves at December 31, 2003  

702

   

806

   

710

   

822

   

1,190

               

4,230

 
Reserves at December 31, 2004  

671

   

961

   

749

   

707

   

1,212

               

4,300

 
Reserves at December 31, 2005  

620

   

1,230

   

793

   

611

   

1,021

   

4,275

   

31

   

4,306

 
Reserves at December 31, 2006   562     1,242     798     571     859     4,032     27     4,059  
     
(1)   The conversion coefficient is 1 cm of natural gas = 0.00615 barrels of oil.
(2)   Data at December 31, 1997, 1998, 1999, 2000, 2001, 2002, 2003, 2004, 2005 and 2006 include 144.2, 139.4, 134.8, 139.8, 129.9, 139, 133.2, 128.4, 132.4 and 131.2 million boe of natural gas in storage in Italy, respectively.

- 105 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Proved oil reserves (1)
(million barrels)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Proved reserves of subsidiaries

 

Proved reserves of affiliates and joint ventures

 

Total

Reserves at December 31, 1996  

316

   

953

   

720

   

416

   

79

               

2,484

 
Purchase of minerals in place                          

254

               

254

 
Revisions of previous estimates  

20

   

76

   

47

   

23

   

21

               

187

 
Improved recovery        

1

   

2

   

12

                     

15

 
Extensions and discoveries  

61

   

34

   

24

   

26

   

5

               

150

 
Production  

(37

)  

(78

)  

(65

)  

(43

)  

(14

)              

(237

)
Sales of minerals in place        

(1

)        

(6

)  

(2

)              

(9

)
Reserves at December 31, 1997  

360

   

985

   

728

   

428

   

343

               

2,844

 
Purchase of minerals in place                                                
Revisions of previous estimates  

(20

)  

86

   

78

   

38

   

(25

)              

157

 
Improved recovery              

17

                           

17

 
Extensions and discoveries  

25

   

31

   

39

   

9

                     

104

 
Production  

(36

)  

(78

)  

(72

)  

(42

)  

(13

)              

(241

)
Sales of minerals in place                                                
Reserves at December 31, 1998  

329

   

1,024

   

790

   

433

   

305

               

2,881

 
Purchase of minerals in place  

6

   

13

         

1

   

79

               

99

 
Revisions of previous estimates  

20

   

107

   

52

   

22

   

44

               

245

 
Improved recovery              

3

                           

3

 
Extensions and discoveries  

5

   

8

   

126

   

2

   

11

               

152

 
Production  

(32

)  

(81

)  

(71

)  

(41

)  

(18

)              

(243

)
Sales of minerals in place                                                
Reserves at December 31, 1999  

328

   

1,071

   

900

   

417

   

421

               

3,137

 
Purchase of minerals in place        

3

   

12

   

46

   

133

               

194

 
Revisions of previous estimates  

(13

)  

42

   

59

   

36

   

166

               

290

 
Improved recovery        

2

   

9

                           

11

 
Extensions and discoveries  

9

   

6

   

32

   

1

   

17

               

65

 
Production  

(28

)  

(84

)  

(78

)  

(45

)  

(39

)              

(274

)
Sales of minerals in place        

(1

)                                

(1

)
Reserves at December 31, 2000  

296

   

1,039

   

934

   

455

   

698

               

3,422

 
Purchase of minerals in place        

118

         

120

   

248

               

486

 
Revisions of previous estimates  

29

   

79

   

91

   

37

   

20

               

256

 
Improved recovery        

11

   

16

   

6

                     

33

 
Extensions and discoveries  

9

   

8

   

21

   

8

   

24

               

70

 
Production  

(25

)  

(84

)  

(81

)  

(74

)  

(50

)              

(314

)
Sales of minerals in place              

(5

)                          

(5

)
Reserves at December 31, 2001  

309

   

1,171

   

976

   

552

   

940

               

3,948

 
Purchase of minerals in place                    

13

   

12

               

25

 
Revisions of previous estimates  

2

   

(31

)  

112

   

4

   

(33

)              

54

 
Improved recovery        

14

   

1

                           

15

 
Extensions and discoveries  

11

   

10

   

14

   

18

   

104

               

157

 
Production  

(30

)  

(92

)  

(81

)  

(77

)  

(54

)              

(334

)
Sales of minerals in place  

(37

)              

(12

)  

(33

)              

(82

)
Reserves at December 31, 2002  

255

   

1,072

   

1,022

   

498

   

936

               

3,783

 
Purchase of minerals in place                    

86

                     

86

 
Revisions of previous estimates  

21

   

51

   

59

   

52

   

153

               

336

 
Improved recovery        

15

   

16

                           

31

 
Extensions and discoveries  

6

   

32

   

28

         

214

               

280

 
Production  

(30

)  

(90

)  

(87

)  

(86

)  

(64

)              

(357

)
Sales of minerals in place                    

(21

)                    

(21

)

- 106 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Proved oil reserves (1)
(million barrels)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Proved reserves of subsidiaries

 

Proved reserves of affiliates and joint ventures

 

Total

Reserves at December 31, 2003  

252

   

1,080

   

1,038

   

529

   

1,239

               

4,138

 
Revisions of previous estimates  

(1

)  

(22

)  

44

   

12

   

(18

)              

15

 
Improved recovery        

11

   

48

   

4

                     

63

 
Extensions and discoveries  

4

   

20

   

34

   

4

   

144

               

206

 
Production  

(30

)  

(94

)  

(104

)  

(74

)  

(75

)              

(377

)
Sales of minerals in place        

(2

)  

(4

)  

(25

)  

(6

)              

(37

)
Reserves at December 31, 2004  

225

   

967

   

1,047

   

450

   

1,283

   

3,972

   

36

   

4,008

 
Purchase of minerals in place  

2

         

6

         

47

   

55

         

55

 
Revisions of previous estimates  

33

   

36

   

(47

)  

27

   

(88

)  

(39

)  

(9

)  

(48

)
Improved recovery        

43

   

29

         

15

   

87

         

87

 
Extensions and discoveries        

26

   

14

   

21

   

16

   

77

         

77

 
Production  

(32

)  

(111

)  

(113

)  

(65

)  

(83

)  

(404

)  

(2

)  

(406

)
Sales of minerals in place                                     

  

          

  

 
Reserves at December 31, 2005  

228

   

961

   

936

   

433

   

1,19

   

3,748

   

25

   

3,773

 
Purchase of minerals in place                                                
Revisions of previous estimates   15     61     (85 )   20     53     64     1     65  
Improved recovery         49     41           14     104     1     105  
Extensions and discoveries         30     11           62     103           103  
Production   (28 )   (119 )   (117 )   (65 )   (61 )   (390 )   (3 )   (393 )
Sales of minerals in place                     (2 )   (170 )   (172 )         (172 )
Reserves at December 31, 2006   215     982     786     386     1,088     3,457     24     3,481  

  

Proved developed oil reserves
Reserves at December 31, 1996  

222

   

712

   

433

   

306

   

43

               

1,716

 
Reserves at December 31, 1997  

226

   

680

   

429

   

287

   

50

               

1,672

 
Reserves at December 31, 1998  

180

   

689

   

452

   

315

   

70

               

1,706

 
Reserves at December 31, 1999  

172

   

681

   

473

   

276

   

148

               

1,750

 
Reserves at December 31, 2000  

144

   

650

   

487

   

303

   

189

               

1,773

 
Reserves at December 31, 2001  

171

   

685

   

539

   

476

   

443

               

2,314

 
Reserves at December 31, 2002  

168

   

610

   

554

   

426

   

483

               

2,241

 
Reserves at December 31, 2003  

173

   

640

   

560

   

464

   

610

               

2,447

 
Reserves at December 31, 2004  

174

   

655

   

588

   

386

   

668

               

2,471

 
Reserves at December 31, 2005  

149

   

697

   

568

   

353

   

564

   

2,331

   

19

   

2,350

 
Reserves at December 31, 2006   136     713     546     329     402     2,126     18     2,144  
     
(1)   Including condensates and natural gas liquids.

- 107 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Proved natural gas reserves
(billion cubic feet)  

Italy (1)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated subsidiaries

 

Total joint ventures and affiliates

 

Total

Reserves at December 31, 1996   7,402     2,704     736     1,316     286     12,444           12,444  
Purchase of minerals in place   208     4                       212           212  
Revisions of previous estimates   64     9     (7 )   3     22     91           91  
Improved recovery                     14           14           14  
Extensions and discoveries   127     478           103           708           708  
Production   (594 )   (41 )   (8 )   (95 )   (34 )   (772 )         (772 )
Sales of minerals in place                     (29 )         (29 )         (29 )
Reserves at December 31, 1997   7,207     3,154     721     1,312     274     12,668           12,668  
Revisions of previous estimates   187     230     (76 )   21     3     365           365  
Extensions and discoveries   242     504     58     104     425     1,333           1,333  
Production   (659 )   (54 )   (7 )   (88 )   (43 )   (851 )         (851 )
Reserves at December 31, 1998   6,977     3,834     696     1,349     659     13,515           13,515  
Purchase of minerals in place                     22     81     123           123  
Revisions of previous estimates   22     585     (28 )   37     (261 )   355           355  
Extensions and discoveries   33     171     308     2     13     527           527  
Production   (594 )   (105 )   (12 )   (79 )   (65 )   (855 )         (855 )
Reserves at December 31, 1999   6,439     4,504     964     1,331     427     13,665           13,665  
Purchase of minerals in place                     195     150     345           345  
Revisions of previous estimates   156     255     (19 )   (23 )   379     748           748  
Improved recovery         2                       2           2  
Extensions and discoveries   40     546           8     299     893           893  
Production   (510 )   (155 )   (23 )   (93 )   (100 )   (881 )         (881 )
Reserves at December 31, 2000   6,125     5,152     922     1,418     1,155     14,772           14,772  
Purchase of minerals in place   17                 501     1,093     1,611           1,611  
Revisions of previous estimates   (37 )   539     12     148     833     1,495           1,495  
Extensions and discoveries   66     1     18     4     202     291           291  
Production (2)   (531 )   (183 )   (27 )   (175 )   (177 )   (1,093 )         (1,093 )
Sales of minerals in place                     (4 )         (4 )         (4 )
Reserves at December 31, 2001   5,640     5,509     925     1,892     3,106     17,072           17,072  
Purchase of minerals in place                     87           87           87  
Revisions of previous estimates   21     257     8     115     1,238     1,639           1,639  
Extensions and discoveries   105     9     636     74     223     1,047           1,047  
Production (2)   (456 )   (212 )   (36 )   (201 )   (228 )   (1,133 )         (1,133 )
Sales of minerals in place   (15 )               (68 )         (83 )         (83 )
Reserves at December 31, 2002   5,295     5,563     4,533     4,899     4,339     18,629           18,629  
Purchase of minerals in place   10                 425     8     443           443  
Revisions of previous estimates   (768 )   (123 )   172     139     325     (255 )         (255 )
Extensions and discoveries   84     242                 100     426           426  
Production (2)   (455 )   (215 )   (49 )   (229 )   (276 )   (1,224 )         (1,224 )
Sales of minerals in place                     (11 )         (11 )         (11 )
Reserves at December 31, 2003   4,166     5,467     1,656     2,223     4,496     18,008           18,008  
Revisions of previous estimates   105     814     129     75     84     1,207           1,207  
Improved recovery               10                 10           10  
Extensions and discoveries   29     420           38     222     709           709  
Production (2)   (409 )   (247 )   (66 )   (220 )   (303 )   (1,245 )         (1,245 )
Sales of minerals in place   (73 )   (1 )         (65 )   (115 )   (254 )         (254 )
Reclassification 2004 affiliates and joint ventures data         (21 )   (2 )         (134 )   (157 )   157        

- 108 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Proved natural gas reserves
(billion cubic feet)  

Italy (1)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated subsidiaries

 

Total joint ventures and affiliates

 

Total

Reserves at December 31, 2004   3,818     6,432     1,727     2,051     4,250     18,278     157     18,435  
Purchase of minerals in place   63           8           222     293           293  
Revisions of previous estimates   159     (6 )   (9 )   (18 )   (368 )   (242 )   (47 )   (289 )
Improved recovery         11                       11           11  
Extensions and discoveries   1     37     309     50     56     453     (20 )   433  
Production (2)   (365 )   (357 )   (70 )   (219 )   (281 )   (1,292 )         (1,292 )
Reserves at December 31, 2005   3,676     6,117     1,965     1,864     3,879     17,501     90     17,591  
Purchase of minerals in place                     4           4           4  
Revisions of previous estimates   36     154     31     53     230     504     (7 )   497  
Extensions and discoveries   19     146     34     1     132     332           332  
Production (2)   (340 )   (471 )   (103 )   (218 )   (305 )   (1,437 )   (15 )   (1,451 )
Sales of minerals in place                     (7 )         (7 )         (7 )
Reserves at December 31, 2006   3,391     5,946     1,927     1,697     3,936     16,897     68     16,965  

 

Proved developed natural gas reserves
Reserves at December 31, 1997   4,442     312     144     790     132     5,820           5,820  
Reserves at December 31, 1998   4,115     516     137     838     184     5,790           5,790  
Reserves at December 31, 1999   4,201     668     653     811     311     6,644           6,644  
Reserves at December 31, 2000   4,012     1,009     595     810     649     7,075           7,075  
Reserves at December 31, 2001   3,665     1,103     584     1,721     1,221     8,294           8,294  
Reserves at December 31, 2002   3,397     1,084     863     1,727     1,283     8,354           8,354  
Reserves at December 31, 2003   2,966     962     866     2,075     3,355     10,224           10,225  
Reserves at December 31, 2004   2,850     1,760     924     1,845     3,122     10,501           10,501  
Reserves at December 31, 2005   2,704     3,060     1,289     1,484     2,622     11,159     70     11,229  
Reserves at December 31, 2006   2,449     3,042     1,447     1,395     2,616     10,949     48     10,997  
     
(1)   Including 808, 782, 756, 783, 728, 779, 747, 737, 760 and 754 billion cubic feet of natural gas held in storage at December 31, 1997, 1998, 1999, 2000, 2001, 2002, 2003, 2004, 2005 and 2006 respectively.
(2)   Starting from 2001 include volumes consumed in operations (34, 47, 53, 80, 93 and 103 billion cubic feet in 2001, 2002, 2003, 2004, 2005 and 2006, respectively).

- 109 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Results of operations from oil and gas producing activities (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total joint venture and affiliates

 

Total

Year ended December 31, 1997                                    
Revenues:                                    
     sales and transfers to affiliates  

2,701

   

781

   

56

         

7

   

3,545

 
     sales to unaffiliated entities  

57

   

464

   

994

   

874

   

258

   

2,647

 
   

2,758

   

1,245

   

1,050

   

874

   

265

   

6,192

 
Production costs  

(306

)  

(393

)  

(316

)  

(231

)  

(58

)  

(1,304

)
Exploration expenses  

(151

)  

(133

)  

(63

)  

(33

)  

(97

)  

(477

)
Depreciation, amortization and writedowns  

(452

)  

(273

)  

(214

)  

(422

)  

(88

)  

(1,449

)
Other income (expense)  

(133

)  

(19

)  

(70

)  

6

   

24

   

(192

)
Pretax income from producing activities  

1,716

   

427

   

387

   

194

   

46

   

2,770

 
Estimated income taxes  

(915

)  

(225

)  

(263

)  

(99

)  

(12

)  

(1,514

)
Results of operations from E&P activities  

801

   

202

   

124

   

95

   

34

   

1,256

 
                                     
Year ended December 31, 1998                                    
Revenues:                                    
     sales and transfers to affiliates  

2,216

   

573

   

20

         

3

   

2,812

 
     sales to unaffiliated entities  

57

   

256

   

711

   

674

   

185

   

1,883

 
   

2,273

   

830

   

732

   

674

   

186

   

4,695

 
Production costs  

(329

)  

(364

)  

(254

)  

(211

)  

(50

)  

(1,208

)
Exploration expenses  

(154

)  

(95

)  

(105

)  

(35

)  

(86

)  

(475

)
Depreciation, amortization and writedowns  

(787

)  

(254

)  

(512

)  

(517

)  

(92

)  

(2,162

)
Other income (expense)  

(98

)  

(21

)  

(102

)  

(10

)  

(51

)  

(282

)
Pretax income from producing activities  

905

   

95

   

(241

)  

(99

)  

(91

)  

568

 
Estimated income taxes  

(382

)  

(58

)  

(74

)  

(7

)  

(1

)  

(522

)
Results of operations from E&P activities  

523

   

37

   

(316

)  

(106

)  

(92

)  

46

 
                                     
Year ended December 31, 1999                                    
Revenues:                                    
     sales and transfers to affiliates  

1,919

   

958

   

1,075

   

650

   

138

   

4,740

 
     sales to unaffiliated entities  

499

   

506

   

81

   

205

   

222

   

1,513

 
   

2,418

   

1,464

   

1,156

   

855

   

360

   

6,253

 
Production costs  

(352

)  

(370

)  

(353

)  

(199

)  

(52

)  

(1,326

)
Exploration expenses  

(120

)  

(69

)  

(61

)  

(39

)  

(83

)  

(372

)
Depreciation, amortization and writedowns  

(462

)  

(316

)  

(253

)  

(336

)  

(81

)  

(1,448

)
Other income (expense)  

(183

)  

(99

)  

(91

)  

3

   

(77

)  

(447

)
Pretax income from producing activities  

1,301

   

610

   

398

   

284

   

67

   

2,660

 
Estimated income taxes  

(542

)  

(254

)  

(219

)  

(110

)  

(19

)  

(1,144

)
Results of operations from E&P activities  

759

   

356

   

179

   

174

   

48

   

1,516

 
                                     
Year ended December 31, 2000                                    
Revenues:                                    
     sales and transfers to affiliates  

3,336

   

1,748

   

2,114

   

1,205

   

531

   

8,934

 
     sales to unaffiliated entities  

136

   

1,134

   

190

   

373

   

660

   

2,493

 
   

3,472

   

2,882

   

2,304

   

1,578

   

1,191

   

11,427

 
Production costs  

(399

)  

(459

)  

(517

)  

(238

)  

(125

)  

(1,738

)
Exploration expenses  

(192

)  

(84

)  

(60

)  

(45

)  

(180

)  

(561

)
Depreciation, amortization and writedowns  

(407

)  

(393

)  

(327

)  

(358

)  

(375

)  

(1,860

)
Other income (expense)  

(30

)  

(196

)  

(132

)  

(55

)  

(117

)  

(530

)
Pretax income from producing activities  

2,444

   

1,750

   

1,268

   

882

   

394

   

6,738

 
Estimated income taxes  

(986

)  

(877

)  

(678

)  

(479

)  

(78

)  

(3,098

)
Results of operations from E&P activities  

1,458

   

873

   

590

   

403

   

316

   

3,640

 

- 110 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Results of operations from oil and gas producing activities (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total joint venture and affiliates

 

Total

Year ended December 31, 2001                                    
Revenues:                                    
     sales and transfers to affiliates  

3,160

   

1,440

   

1,807

   

1,265

   

322

   

7,994

 
     sales to unaffiliated entities  

140

   

1,181

   

169

   

1,250

   

1,271

   

4,011

 
   

3,300

   

2,621

   

1,976

   

2,515

   

1,593

   

12,005

 
Operating expenses  

(327

)  

(337

)  

(221

)  

(495

)  

(270

)  

(1,650

)
Production taxes  

(152

)  

(124

)  

(256

)  

(27

)  

(36

)  

(595

)
Exploration expenses  

(77

)  

(104

)  

(70

)  

(51

)  

(326

)  

(628

)
Depreciation, amortization and writedowns  

(474

)  

(417

)  

(315

)  

(704

)  

(612

)  

(2,522

)
Other income (expense)  

(87

)  

(129

)  

(129

)  

(79

)  

(214

)  

(638

)
Pretax income from producing activities  

2,183

   

1,510

   

985

   

1,159

   

135

   

5,972

 
Estimated income taxes  

(877

)  

(605

)  

(628

)  

(672

)  

(136

)  

(2,918

)
Results of operations from E&P activities  

1,306

   

905

   

357

   

487

   

(1

)  

3,054

 
                                     
Year ended December 31, 2002                                    
Revenues:                                    
     sales and transfers to affiliates  

2,871

   

1,673

   

1,856

   

1,748

   

281

   

8,429

 
     sales to unaffiliated entities  

253

   

1,226

   

186

   

695

   

1,414

   

3,774

 
   

3,124

   

2,899

   

2,042

   

2,443

   

1,695

   

12,203

 
Operating expenses  

(218

)  

(352

)  

(317

)  

(490

)  

(237

)  

(1,614

)
Production taxes  

(138

)  

(110

)  

(210

)  

(20

)  

(47

)  

(525

)
Exploration expenses  

(80

)  

(71

)  

(116

)  

(117

)  

(294

)  

(678

)
Depreciation, amortization and writedowns  

(528

)  

(532

)  

(390

)  

(863

)  

(758

)  

(3,071

)
Other income (expense)  

(258

)  

(186

)  

(122

)  

(47

)  

(183

)  

(796

)
Pretax income from producing activities  

1,902

   

1,648

   

887

   

906

   

176

   

5,519

 
Estimated income taxes  

(751

)  

(852

)  

(578

)  

(445

)  

(83

)  

(2,709

)
Results of operations from E&P activities  

1,151

   

796

   

309

   

461

   

93

   

2,810

 
                                     
Year ended December 31, 2003                                    
Revenues:                                    
     sales and transfers to affiliates  

2,609

   

1,469

   

1,946

   

1,913

   

345

   

8,282

 
     sales to unaffiliated entities  

153

   

1,188

   

164

   

822

   

1,595

   

3,922

 
   

2,762

   

2,657

   

2,110

   

2,735

   

1,940

   

12,204

 
Operating expenses  

(222

)  

(316

)  

(283

)  

(446

)  

(235

)  

(1,502

)
Production taxes  

(136

)  

(97

)  

(235

)  

(11

)  

(79

)  

(558

)
Exploration expenses  

(89

)  

(70

)  

(113

)  

(96

)  

(276

)  

(644

)
Depreciation, amortization and writedowns  

(458

)  

(420

)  

(377

)  

(759

)  

(734

)  

(2,748

)
Other income (expense)  

(170

)  

(264

)  

(121

)  

14

   

(289

)  

(830

)
Accretion of discount (SFAS 143) (2)  

(37

)  

(5

)  

(14

)  

(42

)  

(4

)  

(102

)
Pretax income from producing activities  

1,650

   

1,485

   

967

   

1,395

   

323

   

5,820

 
Estimated income taxes  

(629

)  

(788

)  

(617

)  

(750

)  

(111

)  

(2,895

)
Results of operations from E&P activities  

1,021

   

697

   

350

   

645

   

212

   

2,925

 

- 111 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Results of operations from oil and gas producing activities (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total joint venture and affiliates

 

Total

Year ended December 31, 2004                                    
Revenues:                                    
     sales and transfers to affiliates  

2,633

   

1,868

   

2,762

   

2,083

   

508

   

9,854

 
     sales to unaffiliated entities  

148

   

1,364

   

306

   

709

   

2,086

   

4,613

 
   

2,781

   

3,232

   

3,068

   

2,792

   

2,594

   

14,467

 
Operating expenses  

(223

)  

(292

)  

(322

)  

(405

)  

(289

)  

(1,531

)
Production taxes  

(118

)  

(91

)  

(379

)  

(13

)  

(163

)  

(764

)
Exploration expenses  

(57

)  

(47

)  

(71

)  

(93

)  

(155

)  

(423

)
Depreciation, amortization and writedowns  

(489

)  

(437

)  

(482

)  

(687

)  

(849

)  

(2,944

)
Other income (expense)  

(98

)  

(368

)  

(216

)  

97

   

(208

)  

(793

)
Accretion of discount (SFAS 143) (2)  

(37

)  

(5

)  

(17

)  

(15

)  

(6

)  

(80

)
Pretax income from producing activities  

1,759

   

1,992

   

1,581

   

1,676

   

924

   

7,932

 
Estimated income taxes  

(632

)  

(994

)  

(945

)  

(948

)  

(305

)  

(3,824

)
Results of operations from E&P activities  

1,127

   

998

   

636

   

728

   

619

   

4,108

 
                                           
Year ended December 31, 2005                                          
Revenues:                                          
     sales and transfers to affiliates   3,133     2,813     4,252     2,707     828           13,733  
     sales to unaffiliated entities   161     2,579     394     889     2,883     106     7,012  
    3,294     5,392     4,646     3,596     3,711     106     20,745  
Operating expenses   (261 )   (390 )   (363 )   (417 )   (338 )   (16 )   (1,785 )
Production taxes   (157 )   (98 )   (513 )   (15 )   (207 )   (3 )   (993 )
Exploration expenses   (32 )   (59 )   (38 )   (125 )   (181 )   (30 )   (465 )
Depreciation, amortization and writedowns   (512 )   (711 )   (632 )   (710 )   (1,007 )   (58 )   (3,630 )
Other income (expense)   (205 )   (400 )   (176 )   55     (251 )   7     (970 )
Accretion of discount (SFAS 143) (2)   (45 )   (9 )   (15 )   (31 )   (6 )         (106 )
Pretax income from producing activities   2,082     3,725     2,909     2,353     1,721     6     12,796  
Estimated income taxes   (762 )   (2,197 )   (1,818 )   (1,386 )   (580 )   (19 )   (6,762 )
Results of operations from E&P activities   1,320     1,528     1,091     967     1,141     (13 )   6,034  
                                           
Year ended December 31, 2006                                          
Revenues:                                          
     sales and transfers to affiliates   3,601     4,185     4,817     3,295     973           16,871  
     sales to unaffiliated entities   184     3,012     967     983     2,594     120     7,860  
    3,785     7,197     5,784     4,278     3,567     120     24,731  
Operating expenses   (249 )   (496 )   (475 )   (481 )   (338 )   (18 )   (2,057 )
Production taxes   (181 )   (95 )   (475 )         (82 )   (3 )   (836 )
Exploration expenses   (70 )   (101 )   (90 )   (100 )   (193 )   (9 )   (563 )
Depreciation, amortization and writedowns   (454 )   (869 )   (778 )   (755 )   (1,015 )   (42 )   (3,913 )
Other income (expense)   (287 )   (569 )   (195 )   44     (343 )   7     (1,343 )
Accretion of discount (SFAS 143) (2)   (34 )   (12 )   (12 )   (40 )   (14 )         (112 )
Pretax income from producing activities   2,510     5,055     3,759     2,946     1,582     55     15,907  
Estimated income taxes   (928 )   (2,979 )   (2,094 )   (1,821 )   (600 )   (31 )   (8,453 )
Results of operations from E&P activities   1,582     2,076     1,665     1,125     982     24     7,454  
     
(1)   Results of operations from oil and gas producing activities, including services for the modulation of gas supply due to seasonal swings in demand, represent only those revenues and expenses directly associated with Eni’s oil and gas production.
These amounts do not include any allocation of interest expense or corporate overhead and, therefore, are not necessarily indicative of the contributions to consolidated net earnings of Eni. Such income taxes have been calculated by applying the tax rate of the country where Eni operates to the pretax income from exploration and production activities. Revenues and income taxes include taxes due in PSA’s where Eni’s tax liability is paid by the State Company on behalf of Eni.
(2)   Represents the financial effect of the passage of time relating to Eni’s future asset retirement obligations pursuant to SFAS 143 “Accounting for asset retirement obligations”.

- 112 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Capitalized costs (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total joint venture and affiliates

 

Total

At December 31, 1997                                    
Proved mineral interests  

5,393

   

4,166

   

3,734

   

3,270

   

763

   

17,326

 
Unproved mineral interests        

7

   

188

         

58

   

253

 
Support equipment and facilities  

427

   

15

   

139

   

105

   

17

   

703

 
Incomplete wells and other  

991

   

236

   

321

   

494

   

36

   

2,078

 
Gross capitalized costs  

6,811

   

4,424

   

4,382

   

3,869

   

874

   

20,360

 
Accumulated depreciation, depletion and amortization  

(3,584

)  

(2,267

)  

(2,357

)  

(1,725

)  

(475

)  

(10,408

)
Net capitalized costs  

3,227

   

2,157

   

2,025

   

2,144

   

399

   

9,952

 
                                     
At December 31, 1998                                    
Proved mineral interests  

5,794

   

4,258

   

3,963

   

3,446

   

794

   

18,255

 
Unproved mineral interests        

14

   

177

         

127

   

318

 
Support equipment and facilities  

451

   

23

   

142

   

95

   

14

   

725

 
Incomplete wells and other  

1,172

   

342

   

234

   

651

   

194

   

2,593

 
Gross capitalized costs  

7,417

   

4,637

   

4,516

   

4,192

   

1,129

   

21,891

 
Accumulated depreciation, depletion and amortization  

(4,272

)  

(2,395

)  

(2,689

)  

(2,078

)  

(500

)  

(11,934

)
Net capitalized costs  

3,145

   

2,242

   

1,827

   

2,114

   

629

   

9,957

 
                                     
At December 31, 1999                                    
Proved mineral interests  

6,255

   

5,480

   

5,117

   

4,299

   

1,529

   

22,680

 
Unproved mineral interests  

2

   

130

   

230

         

381

   

743

 
Support equipment and facilities  

487

   

29

   

179

   

149

   

18

   

862

 
Incomplete wells and other  

1,077

   

337

   

181

   

649

   

414

   

2,658

 
Gross capitalized costs  

7,821

   

5,976

   

5,707

   

5,097

   

2,342

   

26,943

 
Accumulated depreciation, depletion and amortization  

(4,609

)  

(3,095

)  

(3,393

)  

(2,610

)  

(663

)  

(14,370

)
Net capitalized costs  

3,212

   

2,881

   

2,314

   

2,487

   

1,679

   

12,573

 
                                     
At December 31, 2000                                    
Proved mineral interests  

6,509

   

6,339

   

5,885

   

5,395

   

3,009

   

27,137

 
Unproved mineral interests        

175

   

281

   

101

   

646

   

1,203

 
Support equipment and facilities  

241

   

30

   

170

   

49

   

28

   

518

 
Incomplete wells and other  

1,195

   

413

   

316

   

547

   

688

   

3,159

 
Gross capitalized costs  

7,945

   

6,957

   

6,652

   

6,092

   

4,371

   

32,017

 
Accumulated depreciation, depletion and amortization  

(4,669

)  

(3,718

)  

(3,935

)  

(2,893

)  

(1,081

)  

(16,296

)
Net capitalized costs  

3,276

   

3,239

   

2,717

   

3,199

   

3,290

   

15,721

 
                                     
At December 31, 2001                                    
Proved mineral interests  

7,645

   

7,624

   

6,723

   

7,986

   

5,382

   

35,360

 
Unproved mineral interests        

672

   

238

   

811

   

1,913

   

3,634

 
Support equipment and facilities  

295

   

56

   

191

   

52

   

47

   

641

 
Incomplete wells and other  

845

   

508

   

501

   

225

   

1,718

   

3,797

 
Gross capitalized costs  

8,785

   

8,860

   

7,653

   

9,074

   

9,060

   

43,432

 
Accumulated depreciation, depletion and amortization  

(5,109

)  

(4,333

)  

(4,378

)  

(3,612

)  

(1,894

)  

(19,326

)
Net capitalized costs  

3,676

   

4,527

   

3,275

   

5,462

   

7,166

   

24,106

 
                                     
At December 31, 2002                                    
Proved mineral interests  

8,030

   

6,782

   

6,377

   

8,112

   

5,638

   

34,939

 
Unproved mineral interests        

527

   

130

   

684

   

1,593

   

2,934

 
Support equipment and facilities  

251

   

43

   

174

   

49

   

51

   

568

 
Incomplete wells and other  

773

   

889

   

795

   

147

   

1,958

   

4,562

 
Gross capitalized costs  

9,054

   

8,241

   

7,476

   

8,992

   

9,240

   

43,003

 
Accumulated depreciation, depletion and amortization  

(5,427

)  

(4,090

)  

(4,048

)  

(4,192

)  

(2,262

)  

(20,019

)
Net capitalized costs  

3,627

   

4,151

   

3,428

   

4,800

   

6,978

   

22,984

 

- 113 -


Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Capitalized costs (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total joint venture and affiliates

 

Total

At December 31, 2003                                    
Proved mineral interests  

8,766

   

6,103

   

6,141

   

8,291

   

6,389

   

35,690

 
Unproved mineral interests        

329

   

83

   

696

   

1,272

   

2,380

 
Support equipment and facilities  

262

   

594

   

208

   

32

   

51

   

1,147

 
Incomplete wells and other  

826

   

1,254

   

1,098

   

223

   

1,413

   

4,814

 
Gross capitalized costs  

9,854

   

8,280

   

7,530

   

9,242

   

9,125

   

44,031

 
Accumulated depreciation, depletion and amortization  

(6,186

)  

(3,799

)  

(3,785

)  

(4,252

)  

(2,657

)  

(20,679

)
Net capitalized costs  

3,668

   

4,481

   

3,745

   

4,990

   

6,468

   

23,352

 
                                     
At December 31, 2004                                    
Proved mineral interests  

9,056

   

7,192

   

6,288

   

7,198

   

7,698

   

37,432

 
Unproved mineral interests        

272

   

70

   

561

   

1,103

   

2,006

 
Support equipment and facilities  

252

   

1,056

   

209

   

33

   

75

   

1,625

 
Incomplete wells and other  

662

   

468

   

1,038

   

397

   

882

   

3,447

 
Gross capitalized costs  

9,970

   

8,988

   

7,605

   

8,189

   

9,758

   

44,510

 
Accumulated depreciation, depletion and amortization  

(6,416

)  

(3,887

)  

(3,907

)  

(3,733

)  

(3,252

)  

(21,195

)
Net capitalized costs  

3,554

   

5,101

   

3,698

   

4,456

   

6,506

   

23,315

 
                                     
At December 31, 2005                                          
Proved mineral interests   9,756     9,321     8,733     8,350     9,463     435     46,058  
Unproved mineral interests   33     197     134     413     1,265     55     2,097  
Support equipment and facilities   253     1,385     272     33     93     9     2,045  
Incomplete wells and other   657     638     728     221     1,895     53     4,192  
Gross capitalized costs   10,699     11,541     9,867     9,017     12,716     552     54,392  
Accumulated depreciation, depletion and amortization   (6,888 )   (5,113 )   (5,193 )   (4,619 )   (4,697 )   (316 )   (26,826 )
Net capitalized costs   3,811     6,428     4,674     4,398     8,019     236     27,566  
                                           
At December 31, 2006                                          
Proved mineral interests   10,780     9,335     8,476     8,790     9,424     436     47,241  
Unproved mineral interests   33     132     385     460     1,106     35     2,151  
Support equipment and facilities   287     1,238     451     33     98     8     2,115  
Incomplete wells and other   655     599     812     300     2,248     51     4,665  
Gross capitalized costs   11,755     11,304     10,124     9,583     12,876     530     56,172  
Accumulated depreciation, depletion and amortization   (7,184 )   (5,403 )   (5,402 )   (5,345 )   (5,187 )   (311 )   (28,832 )
Net capitalized costs   4,571     5,901     4,722     4,238     7,689     219     27,340  
     
(1)   Capitalized costs represent the total expenditure for proved and unproved mineral interests and related support equipment and facilities utilized in oil and gas exploration and production activities, together with related accumulated depreciation, depletion and amortization.

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Contents

ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Costs incurred (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

 

Total joint venture and affiliates

 

Total

Year ended December 31, 1997                                
Proved property acquisitions   48   5   4       2   59       59
Unproved property acquisitions       5   16       15   36       36
Exploration   278   236   112   51   99   776       776
Development   558   212   288   394   66   1,518       1,518
Costs incurred   884   458   420   445   182   2,389       2,389
Year ended December 31, 1998                                
Proved property acquisitions   27   9       67   103   103       103
Unproved property acquisitions   12           82   94   94       94
Exploration   303   171   150   51   112   786       786
Development   488   353   367   583   197   1,988       1,988
Costs incurred   791   563   526   634   458   2,971       2,971
Year ended December 31, 1999                                
Proved property acquisitions   54   102   9       380   545       545
Unproved property acquisitions   2   102   34       234   372       372
Exploration   194   92   87   44   121   538       538
Development   433   356   357   400   318   1,864       1,864
Costs incurred   683   652   487   444   1,053   3,319       3,319
Year ended December 31, 2000                                
Proved property acquisitions   8   32   443   880   1,363   1,363       1,363
Unproved property acquisitions   30   11   67   149   257   257       257
Exploration   155   151   174   86   326   892       892
Development   567   415   372   346   617   2,317       2,317
Costs incurred   722   604   589   942   1,972   4,829       4,829
Year ended December 31, 2001                                
Proved property acquisitions   14   503       1,411   1,254   3,182       3,182
Unproved property acquisitions   438       495   704   1,637   1,637       1,637
Exploration   89   139   97   166   598   1,089       1,089
Development   600   498   698   328   1,337   3,461       3,461
Costs incurred   703   1,578   795   2,400   3,893   9,369       9,369
Year ended December 31, 2002                                
Proved property acquisitions           104   24   128   128       128
Unproved property acquisitions           22   167   189   189       189
Exploration   69   116   203   84   430   902       902
Development   440   724   986   316   1,622   4,088       4,088
Costs incurred   509   840   1,189   526   2,243   5,307       5,307
Year ended December 31, 2003                                
Proved property acquisitions           308   8   316   316       316
Unproved property acquisitions           125   6   131   131       131
Exploration   67   80   138   125   243   653       653
Development (2)   449   1,106   1,268   286   1,454   4,563       4,563
Costs incurred   516   1,186   1,406   844   1,711   5,663       5,663
Year ended December 31, 2004                                
Proved property acquisitions                                
Unproved property acquisitions                                
Exploration   64   104   71   66   194   499       499
Development (2)   431   965   881   391   1,407   4,075       4,075
Costs incurred   495   1,069   952   457   1,601   4,574       4,574

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ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Costs incurred (1)
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

 

Total joint venture and affiliates

 

Total

Year ended December 31, 2005                                
Proved property acquisitions   19       16       99   134       134
Unproved property acquisitions   13       44       99   156       156
Exploration   45   153   75   127   264   664   18   682
Development (2)   644   960   909   528   1,396   4,437   31   4,468
Costs incurred   721   1,113   1,044   655   1,858   5,391   49   5,440
Year ended December 31, 2006                                
Proved property acquisitions   139   10               149       149
Unproved property acquisitions                   3   3       3
Exploration   128   270   471   174   305   1,348   26   1,374
Development (2)   1,120   893   963   538   1,365   4,879   31   4,910
Costs incurred   1,387   1,173   1,434   712   1,673   6,379   57   6,436
     
(1)   Costs incurred represent amounts both capitalized and expensed as incurred in connection with oil and gas producing activities.
(2)   Includes euro 84 million, euro 233 million, euro 588 million and euro 1,241 million of costs capitalized during 2003, 2004, 2005 and 2006 for assets retirement obligations pursuant to SFAS 143 “Accounting for asset retirement obligations”.

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ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS

Estimated future cash inflows represent the revenues that would be received from production and are determined by applying year-end prices of oil and gas to the estimated future production of proved reserves. Future price changes are considered only to extent provided by contractual arrangements. Estimated future development and production costs are determined by estimating the expenditures to be incurred in developing and producing the proved reserves at the end of the year. Neither the effects of price and cost escalations nor expected future changes in technology and operating practices have been considered.
The standardized measure is calculated as the excess of future cash inflows from proved reserves less future costs of producing and developing the reserves, future income taxes and a yearly 10% discount factor.
Future cash flows as of December 31, 2004, 2005 and 2006 include amounts that Eni’s Gas & Power segment and other gas companies correspond for storages services, required to support market demand flexibility needs.
  Future production costs include the estimated expenditures related to the production of proved reserves plus any production taxes without consideration of future inflation. Future development costs include the estimated costs of drilling development wells and installation of production facilities, plus the net costs associated with dismantlement and abandonment of wells and facilities, under the assumption that year-end costs continue without considering future inflation. Future income taxes were calculated in accordance with the tax laws of the countries in which Eni operates.
The standardized measure of discounted future net cash flows, related to the preceding proved oil and gas reserves, is calculated in accordance with the requirements of Statement of Financial Accounting Standard No. 69. The standardized measure does not purport to reflect realizable values or fair market value of Eni’s proved reserves. An estimate of fair value would also take into account, among other things, the expected recovery of reserves in excess of proved reserves, anticipated changes in future prices and costs and a discount factor representative of the risks inherent in producing oil and gas.

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ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Standardized measure of discounted future net cash flows
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

  Total consolidated  

Total joint venture and affiliates

 

Total

At December 31, 1997                                    
Future cash inflows  

27,586

   

20,370

   

10,989

   

9,407

   

4,895

   

73,247

 
Future production costs  

(3,585

)  

(6,994

)  

(3,440

)  

(2,674

)  

(1,257

)  

(17,950

)
Future development and abandonment costs  

(2,489

)  

(3,742

)  

(1,318

)  

(1,237

)  

(1,183

)  

(9,969

)
Future net inflows before income taxes  

21,512

   

9,634

   

6,231

   

5,496

   

2,455

   

45,328

 
Future income taxes  

(7,998

)  

(2,615

)  

(3,526

)  

(2,290

)  

(625

)  

(17,054

)
Future net cash flows  

13,514

   

7,019

   

2,705

   

3,206

   

1,830

   

28,274

 
10% discount  

(5,024

)  

(3,979

)  

(1,009

)  

(1,028

)  

(1,116

)  

(12,156

)
Standardized measure of discounted future net cash flows  

8,490

   

3,040

   

1,696

   

2,178

   

714

   

16,118

 
                                     
At December 31, 1998                                    
Future cash inflows  

18,312

   

13,676

   

7,111

   

6,792

   

2,600

   

48,491

 
Future production costs  

(3,134

)  

(6,196

)  

(2,978

)  

(2,700

)  

(836

)  

(15,844

)
Future development and abandonment costs  

(2,544

)  

(3,704

)  

(1,207

)  

(895

)  

(972

)  

(9,322

)
Future net inflows before income taxes  

12,634

   

3,776

   

2,926

   

3,197

   

792

   

23,325

 
Future income taxes  

(4,489

)  

(749

)  

(1,198

)  

(1,062

)  

(192

)  

(7,690

)
Future net cash flows  

8,145

   

3,027

   

1,728

   

2,135

   

600

   

15,635

 
10% discount  

(2,858

)  

(2,027

)  

(650

)  

(608

)  

(433

)  

(6,576

)
Standardized measure of discounted future net cash flows  

5,287

   

1,000

   

1,078

   

1,527

   

167

   

9,059

 
                                     
At December 31, 1999                                    
Future cash inflows  

29,900

   

34,457

   

21,177

   

12,831

   

9,181

   

107,546

 
Future production costs  

(3,972

)  

(7,782

)  

(5,212

)  

(3,528

)  

(1,375

)  

(21,869

)
Future development and abandonment costs  

(2,264

)  

(4,584

)  

(2,711

)  

(893

)  

(1,731

)  

(12,183

)
Future net inflows before income taxes  

23,664

   

22,091

   

13,254

   

8,410

   

6,075

   

73,494

 
Future income taxes  

(9,168

)  

(10,662

)  

(8,012

)  

(4,006

)  

(1,594

)  

(33,442

)
Future net cash flows  

14,496

   

11,429

   

5,242

   

4,404

   

4,481

   

40,052

 
10% discount  

(5,618

)  

(5,886

)  

(2,238

)  

(1,269

)  

(2,288

)  

(17,299

)
Standardized measure of discounted future net cash flows  

8,878

   

5,543

   

3,004

   

3,135

   

2,193

   

22,753

 
                                     
At December 31, 2000                                    
Future cash inflows  

50,505

   

39,551

   

22,057

   

16,761

   

17,778

   

146,652

 
Future production costs  

(6,310

)  

(9,770

)  

(5,875

)  

(3,349

)  

(2,999

)  

(28,303

)
Future development and abandonment costs  

(2,310

)  

(4,981

)  

(2,708

)  

(860

)  

(2,504

)  

(13,363

)
Future net inflows before income taxes  

41,885

   

24,800

   

13,474

   

12,552

   

12,275

   

104,986

 
Future income taxes  

(15,627

)  

(11,524

)  

(7,938

)  

(6,365

)  

(2,835

)  

(44,289

)
Future net cash flows  

26,258

   

13,276

   

5,536

   

6,187

   

9,440

   

60,697

 
10% discount  

(12,203

)  

(7,146

)  

(2,370

)  

(1,867

)  

(4,410

)  

(27,996

)
Standardized measure of discounted future net cash flows  

14,055

   

6,130

   

3,166

   

4,320

   

5,030

   

32,701

 
                                     
At December 31, 2001                                    
Future cash inflows  

32,310

   

37,780

   

20,154

   

17,444

   

20,715

   

128,403

 
Future production costs  

(5,344

)  

(10,941

)  

(5,779

)  

(4,466

)  

(5,073

)  

(31,603

)
Future development and abandonment costs  

(2,577

)  

(5,284

)  

(3,194

)  

(1,593

)  

(2,607

)  

(15,255

)
Future net inflows before income taxes  

24,389

   

21,555

   

11,181

   

11,385

   

13,035

   

81,545

 
Future income taxes  

(8,918

)  

(9,258

)  

(6,374

)  

(5,584

)  

(3,119

)  

(33,253

)
Future net cash flows  

15,471

   

12,297

   

4,807

   

5,801

   

9,916

   

48,292

 
10% discount  

(6,925

)  

(6,612

)  

(1,992

)  

(1,611

)  

(4,381

)  

(21,521

)
Standardized measure of discounted future net cash flows  

8,546

   

5,685

   

2,815

   

4,190

   

5,535

   

26,771

 

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ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

continues Standardized measure of discounted future net cash flows
(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

  Total consolidated  

Total joint venture and affiliates

 

Total

At December 31, 2002                                    
Future cash inflows  

32,809

   

41,797

   

29,242

   

19,645

   

26,500

   

149,993

 
Future production costs  

(4,367

)  

(10,354

)  

(6,795

)  

(4,748

)  

(4,310

)  

(30,574

)
Future development and abandonment costs  

(2,755

)  

(3,880

)  

(2,706

)  

(1,523

)  

(2,459

)  

(13,323

)
Future net inflows before income taxes  

25,687

   

27,563

   

19,741

   

13,374

   

19,731

   

106,096

 
Future income taxes  

(8,885

)  

(12,164

)  

(11,320

)  

(7,598

)  

(5,593

)  

(45,560

)
Future net cash flows  

16,802

   

15,399

   

8,421

   

5,776

   

14,138

   

60,536

 
10% discount  

(7,471

)  

(7,411

)  

(3,534

)  

(1,577

)  

(6,063

)  

(26,056

)
Standardized measure of discounted future net cash flows  

9,331

   

7,988

   

4,887

   

4,199

   

8,075

   

34,480

 
                                     
At December 31, 2003                                    
Future cash inflows  

24,641

   

36,484

   

25,074

   

19,590

   

28,505

   

134,294

 
Future production costs  

(3,879

)  

(7,868

)  

(5,847

)  

(5,458

)  

(4,763

)  

(27,815

)
Future development and abandonment costs  

(2,080

)  

(3,762

)  

(2,005

)  

(1,084

)  

(2,575

)  

(11,506

)
Future net inflows before income taxes  

18,682

   

24,854

   

17,222

   

13,048

   

21,167

   

94,973

 
Future income taxes  

(6,113

)  

(10,296

)  

(8,979

)  

(7,614

)  

(6,073

)  

(39,075

)
Future net cash flows  

12,569

   

14,558

   

8,243

   

5,434

   

15,094

   

55,898

 
10% discount  

(5,056

)  

(6,646

)  

(3,130

)  

(1,872

)  

(7,930

)  

(24,634

)
Standardized measure of discounted future net cash flows  

7,513

   

7,912

   

5,113

   

3,562

   

7,164

   

31,264

 
                                     
At December 31, 2004                                                
Future cash inflows   28,582     40,373     28,395     20,435     32,619     150,404           150,404  
Future production costs   (3,635 )   (7,237 )   (6,664 )   (5,082 )   (4,858 )   (27,476 )         (27,476 )
Future development and abandonment costs   (2,210 )   (4,073 )   (1,873 )   (1,419 )   (2,873 )   (12,448 )         (12,448 )
Future net inflows before income taxes   22,737     29,063     19,858     13,934     24,888     110,480           110,480  
Future income taxes   (7,599 )   (11,487 )   (10,949 )   (8,824 )   (6,736 )   (45,595 )         (45,595 )
Future net cash flows   15,138     17,576     8,909     5,110     18,152     64,885           64,885  
10% discount   (6,006 )   (7,592 )   (3,267 )   (1,350 )   (9,412 )   (27,627 )         (27,627 )
Standardized measure of discounted future net cash flows   9,132     9,984     5,642     3,760     8,740     37,258           37,258  
                                                 
At December 31, 2005                                                
Future cash inflows   36,203     66,100     45,952     30,835     50,590     229,680     1,055     230,735  
Future production costs   (4,609 )   (10,030 )   (9,604 )   (5,632 )   (6,399 )   (36,274 )   (226 )   (36,500 )
Future development and abandonment costs   (2,936 )   (3,960 )   (2,594 )   (1,774 )   (4,059 )   (15,323 )   (89 )   (15,412 )
Future net inflows before income taxes   28,658     52,110     33,754     23,429     40,132     178,083     740     178,823  
Future income taxes   (9,890 )   (22,744 )   (21,056 )   (15,225 )   (12,097 )   (81,012 )   (187 )   (81,199 )
Future net cash flows   18,768     29,366     12,698     8,204     28,035     97,071     553     97,624  
10% discount   (7,643 )   (12,095 )   (4,122 )   (2,155 )   (15,705 )   (41,720 )   (182 )   (41,902 )
Standardized measure of discounted future net cash flows consolidated   11,125     17,271     8,576     6,049     12,330     55,351     371     55,722  
                                                 
At December 31, 2006                                                
Future cash inflows   43,495     64,381     34,935     24,821     48,591     216,223     1,038     217,261  
Future production costs   (6,086 )   (9,707 )   (8,028 )   (6,426 )   (5,915 )   (36,162 )   (224 )   (36,386 )
Future development and abandonment costs   (6,739 )   (5,383 )   (2,865 )   (2,265 )   (4,576 )   (21,828 )   (79 )   (21,907 )
Future net inflows before income taxes   30,670     49,291     24,042     16,130     38,100     158,233     735     158,968  
Future income taxes   (10,838 )   24,639     (14,141 )   (10,901 )   (11,473 )   (71,992 )   (227 )   (72,219 )
Future net cash flows   19,832     24,652     9,901     5,229     26,627     86,241     508     86,749  
10% discount   (11,493 )   (10,631 )   (2,994 )   (1,392 )   (16,504 )   (43,014 )   (154 )   (43,168 )
Standardized measure of discounted future net cash flows consolidated   8,339     14,021     6,907     3,837     10,123     43,227     354     43,581  

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ENI FACT BOOK / SUPPLEMENTAL OIL AND GAS INFORMATION

Changes in standardized measure of discounted future net cash flows
(million euro)  

1997

 

1998

 

1999

 

2000

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Beginning of year   15,438     16,118     9,059     22,753     32,701     26,771     34,480     31,264     37,258     55,722  
Reclassification 2004 affiliates and joint ventures data                                                   (357 )   (371 )
Beginning of year consolidated   15,438     16,118     9,059     22,753     32,701     26,771     34,480     31,264     36,901     55,351  
  Increase (Decrease):                                                            
  sales, net of production costs   (4,888 )   (3,486 )   (4,927 )   (9,689 )   (9,760 )   (10,064 )   (10,144 )   (12,172 )   (17,880 )   (21,739 )
  net changes in sales and transfer prices, net of production costs   (5,034 )   (10,384 )   23,334     11,889     (16,754 )   18,936     (1,050 )   13,031     33,372     4,097  
  extensions, discoveries and improved recovery net of future production and development costs   1,112     666     1,144     1,623     1,027     1,810     1,855     2,806     3,527     3,629  
  changes in estimated future development and abandonment costs   (1,005 )   (642 )   (1,570 )   (1,061 )   (2,527 )   (2,697 )   (3,576 )   (3,437 )   (3,654 )   (6,964 )
  development costs incurred during the period that reduced future development costs   1,375     1,803     1,746     2,125     3,342     4,287     4,864     4,229     3,865     3,558  
  revisions of quantity estimates   1,229     688     2,054     2,736     3,397     1,715     2,348     1,658     47     383  
  accretion of discount   2,997     2,494     1,362     4,226     5,628     4,279     5,585     5,328     6,573     9,489  
  net change in income taxes   4,773     4,819     (12,702 )   (4,102 )   5,618     (9,318 )   105     (4,805 )   (17,327 )   3,060  
  purchase of reserves in place   520           1,032     3,052     4,443     387     1,488           977     10  
  sale of reserves in place   (80 )         (1 )   (7 )   (34 )   (646 )   (222 )   (727 )         (1,252 )
  changes in production rates (timing) and other   (319 )   (3,017 )   2,222     (844 )   (310 )   (980 )   (4,469 )   83     8,950     (6,395 )
End of year consolidated   16,118     9,059     22,753     32,701     26,771     34,480     31,264     37,258     55,351     43,227  
End of year affiliates and joint ventures                                                   371     354  
End of year   16,118     9,059     22,753     32,701     26,771     34,480     31,264     37,258     55,722     43,581  

- 120 -


Contents

ENI FACT BOOK / ENERGY CONVERSION TABLE

Energy conversion table

 

Oil
(average reference density 32.35 °API, relative density 0.8636)    
1 barrel

(bbl)

158.987

  l oil (1)

0.159

  m3 oil

162.602

  m3 gas      

5,742

  ft3 gas
               

5,800,000

 

btu

           
1 barrel/d

(bbl/d)

~50

  t/year                        
1 cubic meter

(m3)

1,000

  l oil

6.29

  bbl

1,033

  m3 gas      

36,481

  ft3 gas
1 tonne oil equivalent

(toe)

1,160.49

  l oil

7.299

  bbl

1.161

  m3 oil

1,187

  m3 gas

41,911

  ft3 gas

 

Gas
     
1 cubic meter

(m3)

0.976

  l oil

0.00615

  bbl

35,314.67

  btu      

35.315

  ft3 gas
1,000 cubic feet

(ft3)

27.637

  l oil

0.1742

  bbl

1,000,000

  btu

27.317

  m3 gas

0.02386

  toe
1,000,000 british thermal unit

(btu)

27.4

  l oil

0.17

  bbl

0.027

  m3 oil

28.3

  m3 gas

1,000

  ft3 gas
1 tonne LNG

(tLNG)

1.2

  toe

8.9

  bbl

52,000,000

  btu      

52,000

  ft3 gas
                           

1,400

  m3 gas

 

Electricity
     
1 megawatthour=1,000 kWh

(MWh)

93.532

  l oil

0.5883

  bbl

0.0955

  m3 oil

96.621

  m3 gas

3,412.14

  ft3 gas
1 teraJoule

(TJ)

25,981.45

  l oil

163.42

  bbl

25.9814

  m3 oil

26,839.46

  m3 gas

947,826.7

  ft3 gas
1,000,000 kilocalories

(kcal)

108.8

  l oil

0.68

  bbl

0.109

  m3 oil

112.4

  m3 gas

3,968.3

  ft3 gas
     
(1)   l oil: liters of oil.

 

 

Conversion of mass
     

kilogram
(kg)

pound
(lb)

metric ton
(t)

kg    

1

2.2046

0.001

lb    

0.4536

1

0.0004536

t    

1,000

22,046

1

Conversion of length
   

meter
(m)

inch
(in)

foot
(ft)

yard
(yd)

m  

1

39.37

3.281

1.093

in  

0.0254

1

0.0833

0.0278

ft  

0.3048

12

1

0.3333

yd  

0.9144

36

3

1

Conversion of volumes
   

cubic foot
(ft3)

barrel
(bbl)

liter
(l)

cubic meter
(m3)

ft3  

1

0.1781

28.32

0.02832

bbl  

5.615

1

159

0.158984

l  

0.035311

0.0063

1

0.001

m3  

35.3107

6.2898

103

1

- 121 -


Contents

Quarterly information

Main financial data (1)

  

  


Italian GAAP

    
    

2002

 

2003

   
 
    

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Net sales from operations   12,705     11,199     10,795     13,223     47,922     14,359     11,578     11,916     13,634     51,487  
Operating income:   2,700     1,875     1,854     2,073     8,502     3,333     1,779     1,897     2,508     9,517  
     Exploration & Production   1,287     1,228     1,327     1,333     5,175     1,735     1,175     1,457     1,379     5,746  
     Gas & Power   1,426     577     375     866     3,244     1,529     539     390     1,169     3,627  
     Refining & Marketing   62     60     122     77     321     117     208     151     107     583  
     Petrochemicals   (68 )   31     50     (139 )   (126 )   (17 )   (34 )   (63 )   (62 )   (176 )
     Engineering & Construction   86     73     73     66     298     60     79     81     91     311  
     Other activities   (45 )   (57 )   (72 )   (40 )   (214 )   (33 )   (130 )   (58 )   (72 )   (293 )
     Corporate and financial companies   (48 )   (37 )   (21 )   (90 )   (196 )   (58 )   (58 )   (61 )   (104 )   (281 )
     Unrealized profit in inventory                                                            
Net income   1,328     879     921     1,411     4,539     2,006     1,084     955     1,540     5,585  
Capital expenditure   1,541     1,919     1,872     2,716     8,048     1,735     2,235     2,145     2,687     8,802  
Investments   196     22     952     196     1,366     3,512     54     537     152     4,255  
Net borrowings at period end   6,713     8,486     9,272     11,141     11,141     11,708     12,795     13,044     13,543     13,543  
    


IFRS

   
   

2004

 

2005

   
 
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Net sales from operations  

14,545

   

13,293

   

13,517

   

16,190

   

57,545

   

17,445

   

16,665

   

18,121

   

21,506

   

73,728

 
Operating income:  

3,212

   

2,649

   

2,987

   

3,551

   

12,399

   

4,450

   

3,711

   

4,270

   

4,396

   

16,827

 
     Exploration & Production  

1,665

   

1,828

   

2,439

   

2,253

   

8,185

   

2,567

   

2,776

   

3,682

   

3,567

   

12,592

 
     Gas & Power  

1,551

   

566

   

433

   

878

   

3,428

   

1,563

   

592

   

525

   

641

   

3,321

 
     Refining & Marketing  

125

   

301

   

317

   

337

   

1,080

   

269

   

596

   

663

   

329

   

1,857

 
     Petrochemicals  

5

   

62

   

89

   

164

   

320

   

158

   

58

   

(51

)  

37

   

202

 
     Oilfield Services Construction and Engineering  

60

   

55

   

46

   

42

   

203

   

65

   

53

   

60

   

129

   

307

 
     Other activities  

(96

)  

(122

)  

(93

)  

(84

)  

(395

)  

(62

)  

(197

)  

(378

)  

(297

)  

(934

)
     Corporate and financial companies  

(49

)  

(62

)  

(179

)  

(73

)  

(363

)  

(53

)  

(158

)  

(125

)  

(41

)  

(377

)
     Unrealized profit in inventory  

(49

)  

21

   

(65

)  

34

   

(59

)  

(57

)  

(9

)  

(106

)  

31

   

(141

)
Net income  

2,001

   

1,364

   

1,585

   

2,109

   

7,059

   

2,445

   

1,898

   

2,340

   

2,105

   

8,788

 
Capital expenditure  

1,729

   

2,030

   

1,745

   

1,995

   

7,499

   

1,474

   

1,732

   

1,744

   

2,464

   

7,414

 
Investments  

25

   

45

   

81

   

165

   

316

   

23

    25    

38

   

85

   

146

 
Net borrowings at period end  

11,612

   

13,116

   

11,522

   

10,443

   

10,443

   

8,022

   

9,411

   

6,354

   

10,475

   

10,475

 
           


IFRS

       
           

2006

       
        

I quarter

  

II quarter

  

III quarter

  

IV quarter

     
Net sales from operations   23,584     20,739     20,366     21,416     86,105  
Operating income:   5,595     4,947     4,828     3,957     19,327  
     Exploration & Production   4,303     4,095     4,041     3,141     15,580  
     Gas & Power   1,199     708     592     1,303     3,802  
     Refining & Marketing   89     366     250     (386 )   319  
     Petrochemicals   39     30     31     72     172  
     Engineering & Construction   83     128     145     149     505  
     Other activities   (65 )   (151 )   (185 )   (221 )   (622 )
     Corporate and financial companies   (51 )   (91 )   (65 )   (89 )   (296 )
     Unrealized profit in inventory   (2 )   (138 )   19     (12 )   (133 )
Net income   2,974     2,301     2,422     1,520     9,217  
Capital expenditure   1,340     1,714     1,835     2,944     7,833  
Investments   19     38     19     19     95  
Net borrowings at period end   6,291     6,394     3,850     6,767     6,767  
     
(1)   Quarterly data are unaudited.

 

Key market indicator
   


2002

   
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Average price of Brent dated crude oil (1)  

21.14

   

25.04

   

26.95

   

26.78

   

24.98

 
Average EUR/USD exchange rate  

0.876

   

0.919

   

0.984

   

1.000

   

0.946

 
Average price in euro of Brent dated crude oil (2)  

24.13

   

27.25

   

27.39

   

26.78

   

26.41

 
Average European refining margins (3)  

0.21

   

0.73

   

0.75

   

1.49

   

0.80

 
Euribor %  

3.4

   

3.4

   

3.4

   

3.1

   

3.3

 
   


2003

 

2004

   
 
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Average price of Brent dated crude oil (1)  

31.51

   

26.03

   

28.41

   

29.42

   

28.84

   

31.95

   

36.36

   

41.54

   

44.00

   

38.46

 
Average EUR/USD exchange rate  

1.073

   

1.136

   

1.124

   

1.189

   

1.131

   

1.250

   

1.204

   

1.222

   

1.296

   

1.244

 
Average price in euro of Brent dated crude oil (2)  

29.36

   

22.90

   

25.26

   

24.74

   

25.50

   

25.56

   

29.37

   

33.99

   

33.95

   

30.72

 
Average European refining margins (3)  

3.81

   

2.17

   

2.28

   

2.34

   

2.65

   

2.21

   

5.26

   

4.28

   

5.75

   

4.35

 
Euribor %  

2.7

   

2.4

   

2.1

   

2.2

   

2.3

   

2.1

   

2.1

   

2.1

   

2.2

   

2.1

 
   


2005

 

2006

   
 
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Average price of Brent dated crude oil (1)   47.50     51.59     61.54     56.90     54.38     61.75     69.62     69.49     59.68     65.14  
Average EUR/USD exchange rate   1.311     1.260     1.220     1.189     1.244     1.202     1.256     1.274     1.290     1.256  
Average price in euro of Brent dated crude oil (2)   36.23     40.94     50.44     47.86     43.71     51.37     55.43     54.55     46.26     51.86  
Average European refining margins (3)   4.26     6.78     7.02     5.05     5.78     2.95     5.77     4.27     2.18     3.79  
Euribor %   2.1     2.1     2.1     2.3     2.2     2.6     2.9     3.2     3.6     3.1  
        
(1)    In USD/barrel. Source: Platt’s Oilgram.
(2)    Eni calculation.
(3)    In US dollars per barrel FOB Mediterranean Brent crude. From 1995 lead-free gasoline. Eni elaborations on Platt’s Oilgram data.

- 122 -


Contents
Main operating data
   


Italian GAAP

   
   

2002

   
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Daily production of oil (kbbls/d)  

910

   

927

   

908

   

939

   

921

 
Daily production of natural gas (kboe/d)  

531

   

541

   

543

   

588

   

551

 
Daily production of hydrocarbons (kboe/d)  

1,441

   

1,468

   

1,451

   

1,527

   

1,472

 
     Italy  

311

   

315

   

320

   

316

   

316

 
     North Africa  

330

   

349

   

360

   

376

   

354

 
     West Africa  

237

   

238

   

240

   

235

   

237

 
     North Sea  

313

   

313

   

271

   

337

   

308

 
     Rest of World  

250

   

253

   

260

   

263

   

257

 
Production sold (mmboe)  

132.8

   

123.3

   

124.7

   

142.5

   

523.3

 
Sales of natural gas to third parties (bcm)  

21.88

   

12.75

   

11.28

   

18.21

   

64.12

 
Own consumption of natural gas (bcm)  

0.51

   

0.5

   

0.5

   

0.51

   

2.02

 
Sales to third parties and own consumption (bcm)  

22.39

   

13.25

   

11.78

   

18.72

   

66.14

 
Sales of natural gas of Eni’s affiliates (net to Eni) (bcm)                          

2.4

 
Total sales and own consumption of natural gas (bcm)  

22.39

   

13.25

   

11.78

   

18.72

   

68.54

 
Volumes transported on behalf of third parties in Italy (bcm)  

4.55

   

4.79

   

4.94

   

5.56

   

19.84

 
Electricity sales (TWh)  

1.37

   

1.24

   

1.06

   

1.34

   

5.01

 
Sales of refined products (mmtonnes):  

12.22

   

13.42

   

13.2

   

13.18

   

52.24

 
     Retail sales in Italy  

2.67

   

2.81

   

2.87

   

2.79

   

11.14

 
     Wholesale sales in Italy  

2.66

   

2.54

   

2.55

   

2.89

   

10.64

 
     Retail sales outside Italy  

0.96

   

1.05

   

1

   

1

   

4.01

 
     - Rest of Europe  

0.58

   

0.64

   

0.69

   

0.66

   

2.57

 
     - Africa and Brazil  

0.38

   

0.41

   

0.31

   

0.34

   

1.44

 
     Wholesale sales outside Italy  

1.29

   

1.32

   

1.59

   

1.45

   

5.65

 
     Other sales  

4.7

   

5.75

   

5.25

   

5.1

   

20.8

 
   


Italian GAAP

 

IFRS

   
 
   

2003

 

2004

   
 
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Daily production of oil (kbbls/d)  

925

   

978

   

985

   

1,035

   

981

   

1,016

   

1,026

   

1,003

   

1,090

   

1,034

 
Daily production of natural gas (kboe/d)  

573

   

578

   

571

   

602

   

581

   

612

   

595

   

542

   

614

   

590

 
Daily production of hydrocarbons (kboe/d)  

1,498

   

1,556

   

1,556

   

1,637

   

1,562

   

1,628

   

1,621

   

1,545

   

1,704

   

1,624

 
     Italy  

310

   

302

   

295

   

293

   

300

   

278

   

263

   

271

   

272

   

271

 
     North Africa  

333

   

343

   

357

   

369

   

351

   

367

   

374

   

367

   

411

   

380

 
     West Africa  

235

   

262

   

265

   

278

   

260

   

301

   

302

   

320

   

339

   

316

 
     North Sea  

367

   

349

   

317

   

348

   

345

   

334

   

335

   

258

   

306

   

308

 
     Rest of World  

253

   

300

   

322

   

349

   

306

   

348

   

347

   

329

   

376

   

349

 
Production sold (mmboe)  

128.6

   

138.7

   

141.2

   

147.7

   

556.2

   

143.4

   

141.7

   

138.5

   

152.9

   

576.5

 
Sales of natural gas to third parties (bcm)  

23.54

   

13.79

   

11.84

   

20.32

   

69.49

   

24.78

   

15.15

   

12.68

   

20.18

   

72.79

 
Own consumption of natural gas (bcm)  

0.51

   

0.39

   

0.4

   

0.6

   

1.9

   

0.81

   

0.87

   

0.97

   

1.05

   

3.7

 
Sales to third parties and own consumption (bcm)  

24.05

   

14.18

   

12.24

   

20.92

   

71.39

   

25.59

   

16.02

   

13.65

   

21.23

   

76.49

 
Sales of natural gas of Eni’s affiliates (net to Eni) (bcm)  

1.16

   

2.18

   

1.42

   

2.18

   

6.94

   

2.06

   

1.59

   

1.52

   

2.15

   

7.32

 
Total sales and own consumption of natural gas (bcm)  

25.21

   

16.36

   

13.66

   

23.1

   

78.33

   

27.65

   

17.61

   

15.17

   

23.38

   

83.81

 
Volumes transported on behalf of third parties in Italy (bcm)  

5.9

   

6.28

   

5.87

   

6.58

   

24.63

   

6.89

   

7.2

   

6.7

   

7.47

   

28.26

 
Electricity sales (TWh)  

1.26

   

1.25

   

1.16

   

1.88

   

5.55

   

2.51

   

3.57

   

3.56

   

4.21

   

13.85

 
Sales of refined products (mmtonnes):  

11.82

   

12.5

   

12.32

   

13.27

   

50.43

   

12.73

   

14.34

   

13.04

   

13.43

   

53.54

 
     Retail sales in Italy  

2.57

   

2.81

   

2.84

   

2.77

   

10.99

   

2.55

   

2.78

   

2.83

   

2.77

   

10.93

 
     Wholesale sales in Italy  

2.5

   

2.48

   

2.45

   

2.92

   

10.35

   

2.56

   

2.58

   

2.65

   

2.91

   

10.7

 
     Retail sales outside Italy  

0.88

   

1.02

   

1.18

   

1.12

   

4.2

   

1.08

   

1.15

   

0.93

   

0.88

   

4.04

 
     - Rest of Europe  

0.61

   

0.72

   

0.88

   

0.81

   

3.02

   

0.8

   

0.86

   

0.93

   

0.88

   

3.47

 
     - Africa and Brazil  

0.27

   

0.3

   

0.3

   

0.31

   

1.18

   

0.28

   

0.29

               

0.57

 
     Wholesale sales outside Italy  

1.44

   

1.57

   

1.55

   

1.45

   

6.01

   

1.39

   

1.65

   

1.1

   

1.16

   

5.3

 
     Other sales  

4.56

   

4.75

   

4.43

   

5.14

   

18.88

   

5.15

   

6.18

   

5.53

   

5.71

   

22.57

 

 

   

IFRS

   
   

2005

 

2006

   
 
   

I quarter

 

II quarter

 

III quarter

 

IV quarter

     

I quarter

 

II quarter

 

III quarter

 

IV quarter

   
Daily production of oil (kbbls/d)   1,100   1,107   1,106   1,132   1,111   1,143   1,056   1,041   1,079   1,079
Daily production of natural gas (kboe/d)   603   618   609   674   626   684   692   668   718   690
Daily production of hydrocarbons (kboe/d)   1,703   1,725   1,715   1,806   1,737   1,827   1,748   1,709   1,796   1,770
     Italy   265   268   256   254   261   247   237   235   232   238
     North Africa   432   465   502   522   480   541   555   554   571   555
     West Africa   327   326   347   372   343   382   368   365   372   372
     North Sea   290   286   265   291   283   298   284   254   291   282
     Rest of World   389   380   345   367   370   359   304   301   330   323
Production sold (mm boe)   148.0   153.4   152.5   161.0   614.9   159.5   154.1   152.3   159.2   625.1
Sales of natural gas to third parties (bcm)   24.55   15.65   13.95   22.93   77.08   26.20   16.11   14.97   22.35   79.63
Own consumption of natural gas (bcm)   1.25   1.34   1.48   1.47   5.54   1.47   1.61   1.50   1.55   6.13
Sales to third parties and own consumption (bcm)   25.80   16.99   15.43   24.40   82.62   27.67   17.72   16.47   23.90   85.76
Sales of natural gas of Eni’s affiliates (net to Eni) (bcm)   2.27   1.53   1.23   2.05   7.08   2.41   1.65   1.62   1.97   7.65
Total sales and own consumption of natural gas (bcm)   28.07   18.52   16.66   26.45   89.70   30.08   19.37   18.09   25.87   93.41
Volumes transported on behalf of third parties in Italy (bcm)   8.34   7.99   6.59   7.30   30.22   8.77   7.72   6.93   7.48   30.90
Electricity sales (TWh)   4.98   5.57   6.15   6.07   22.77   6.42   6.00   6.33   6.07   24.82
Sales of refined products (mmtonnes):   12.30   12.51   13.16   13.66   51.63   12.32   12.55   13.09   13.17   51.13
     Retail sales in Italy   2.52   2.70   2.63   2.20   10.05   2.06   2.20   2.24   2.16   8.66
     Wholesale sales in Italy   2.53   2.54   2.58   2.83   10.48   2.54   2.48   2.46   2.58   10.06
     Retail sales outside Italy   0.83   0.94   0.99   0.91   3.67   0.87   0.95   1.03   0.97   3.82
     - Rest of Europe   0.83   0.94   0.99   0.91   3.67   0.87   0.95   1.03   0.97   3.82
     - Africa and Brazil                                        
     Wholesale sales outside Italy   1.10   1.06   1.14   1.20   4.50   1.13   1.15   1.17   1.15   4.60
     Other sales   5.32   5.27   5.82   6.52   22.93   5.72   5.77   6.19   6.31   23.99

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Contents
 
  Società per Azioni
Headquarters: Rome, Piazzale Enrico Mattei, 1
Capital Stock:
euro 4,005,358,876 fully paid
Tax identification number 00484960588
Branches:
San Donato Milanese (MI) - Via Emilia, 1
San Donato Milanese (MI) - Piazza Ezio Vanoni, 1
 

Investor Relations
Piazza Ezio Vanoni, 1 - 20097 San Donato Milanese (Milan)
Tel. +39-0252051651 - Fax +39-0252031929
e-mail: investor.relations@eni.it

Publications
Financial Statements prepared in accordance with
Legislative Decree No. 127 of April 9, 1991 (in Italian)
Annual Report
Annual Report on Form 20-F
for the Securities and Exchange Commission
Sustainability Report (in Italian and English)
Fact Book (in Italian and English)
Report on the First, the Second and the Third Quarter
(in Italian and English)
Report on the First Half (in Italian)
prepared in accordance with art. 2428 of Italian Civil Code
Report on the First Half (in English)

Internet Home page: www.eni.it
Rome office telephone: +39-0659821
Toll-free number: 800940924
e-mail: segreteriasocietaria.azionisti@eni.it

ADRs/Depositary
Morgan Guaranty Trust Company of New York
ADR Department
60 Wall Street (36th Floor)
New York, New York 10260
Tel. 212-648-3164

ADRs/Transfer agent
Morgan ADR Service Center
2 Heritage Drive
North Quincy, MA 02171
Tel. 617-575-4328

Design: Opera
Cover: Grafica Internazionale - Rome - Italy
Layout and supervision: Korus Srl - Rome - Italy
Digital printing: Mari Group Comunications - Rome - Italy

 


Contents


Table of Contents
Contents


Contents

Phase I of the massive Kashagan development project is progressing toward completion with expected start-up by the end of 2010. This project – intended to produce up to 13 billion barrels of recoverable reserves – will demonstrate again Eni’s ability to deliver in spite of the complexity of tasks and the harshness of environmental conditions. Pictured on the cover is a floating production hub for collecting oil and natural gas from artificial, satellite islands. After an early stage treatment, oil is expected to be transported onshore for further purification and exportation.

     
     
Countries of activity    
     
EUROPE
Austria, Belgium, Croatia, Cyprus, Czech Republic, Denmark, France, Germany, Greece, Hungary, Ireland, Italy, Luxembourg, Malta, Netherlands, Norway, Principality of Monaco, Portugal, Romania, Slovakia, Slovenia, Spain, Switzerland, Turkey, United Kingdom

CIS
Azerbaijan, Georgia, Kazakhstan, Russia, Turkmenistan

AFRICA
Algeria, Angola, Cameroon, Chad, Congo, Côte d’Ivoire, Egypt, Gabon, Libya, Mali, Morocco, Mozambique, Nigeria, Tunisia

MIDDLE EAST
Iran, Kuwait, Oman, Qatar, Saudi Arabia, United Arab Emirates

CENTRAL ASIA
India, Pakistan

SOUTH EAST ASIA AND OCEANIA
Australia, China, East Timor, Indonesia, Malaysia, Papua-New Guinea, Thailand

AMERICAS
Argentina, Brazil, Canada, Ecuador, Mexico, Peru, Trinidad & Tobago, United States, Venezuela
   

 


Table of Contents
3   To our Shareholders
6   Profile of the year
13   Business Review
14   • Exploration & Production
26   • Gas & Power
34   • Refining & Marketing
42   • Engineering & Construction
47   Group results for the year
52   Commitment to sustainable development
60   Financial Information
71   Frequently Used Terms
76   Directors and Officers
83   Investor Information

 

 

 

Eni SpA is the parent company of the Eni Group of companies. Unless otherwise stated, the text does not distinguish between the activities and operations of the parent company and those of its subsidiaries.

The Exploration & Production Division (E&P) is engaged in exploration, development and production activities mainly in Italy, in North and West Africa, in the Caspian Region, in the Gulf of Mexico and in Kazakhstan.
The Gas & Power Division (G&P) conducts gas marketing, supply, transport and distribution activities and power generation activity mainly in Italy and in Europe.
The Refining & Marketing Division (R&M) is engaged in the refining and marketing of petroleum products activities mainly in Italy and Central and West Europe.
The Engineering & Construction Division (E&C) is engaged in the execution of large offshore projects for the oil industry, including subsea pipelaying and construction of production platforms, FPSO units and relevant facilities, drilling services, and the construction of plants in the oil and petrochemical industries.

The term “shareholder” in this report means, unless the context otherwise requires, investors in the equity capital of Eni SpA, both direct and/or indirect.

For definitions of certain financial and operating term see “Frequently used terms” section, on page 71.

“Eni in 2006” report comprises the description of the business, a synthesis of the management’s discussion and analysis of financial condition and results of operations and certain other company information from Eni’s Annual Report for the year ended 31 December 2006. It does not contain sufficient information to allow as full an understanding of financial results, operating performances and business developments of Eni as Eni 2006 Annual Report. It is not deemed to be filed or submitted with any Italian or US market or other regulatory authorities.
You may obtain a copy of “Eni in 2006” and “Eni 2006 Annual Report” on request, free of charge (see the request form on Eni’s web site - www.eni.it - under the section Documents Download>Reports).
“Eni in 2006” and “Eni 2006 Annual Report” may be downloaded from Eni’s web site under the section Investor relations>Reports.
  This report contains certain forward-looking statements particularly those regarding capital expenditure, development and management of oil and gas resources, dividends, share repurchases, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets, and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future.
Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors and other factors discussed elsewhere in this document.

As Eni shares, in the form of ADRs, are listed on the New York Stock Exchange (NYSE), an annual report on Form 20-F will be filed with the US Securities and Exchange Commission in accordance with the US Securities Exchange Act of 1934.
When filed, hard copies may be obtained free of charge (see the request form on Eni’s web site – www.eni.it – under the section Documents Download>Reports). Eni discloses on its Annual Report significant ways in which its corporate governance practices differ from those mandated for US companies under NYSE listing standards.

Eni shares are traded on the Italian Stock Exchange (Mercato Telematico Azionario) and on the New York Stock Exchange (NYSE) under the ticker “E”.

 


Contents

 

 

 

MISSION

We are a major integrated energy company, committed to growth in the activities of finding, producing, transporting, transforming and marketing oil and gas. Eni men and women have a passion for challenges, continuous improvement, excellence and particularly value people, the environment and integrity

 

 

 

 

 

 

 


Contents

ENI IN 2006 / TO OUR SHAREHOLDERS

To our Shareholders

     
         
    Roberto Poli
Chairman
  Paolo Scaroni
CEO

 

2006 was a remarkable year for Eni in terms of both financial performance and operational accomplishments.
Our earnings and cash flow were the highest in our history, driven by continued improvements in performance and consistent execution of our strategy in a broadly favorable trading environment.
In particular, we maintained pleasing production growth despite the impact of disruption in Venezuela, achieved several exploration successes, secured access to promising new acreage and further expanded our global natural gas business.
On top of that, we struck a landmark agreement with Gazprom which extends our gas contracts to 2035 and opens up new opportunities for upstream expansion in Russia.

Financial performance
Our reported net profit of euro 9.2 billion in 2006 was the highest in the history of the Company.
Adjusted net profit rose 12.5% to euro 10.4 billion, representing a return on average capital employed of 22.7%. Net cash generated by operating activities totalled euro 17 billion, allowing us to finance capital expenditure of euro 7.8 billion and to reduce our debt/equity ratio to 0.16. Those strong results enabled us to propose a dividend of euro 1.25 per share to our Annual General Shareholders’ Meeting, up 14% compared to 2005 (euro 1.10 per share), of which euro 0.60 was paid as an interim dividend in October 2006. During the year, we purchased a total of 53.1 million of our own shares for euro 1.2 billion, bringing the total cash returned to shareholders for the year to euro 5.8 billion. Our total shareholder return was 14.8%, making this the fifth year running that we have outperformed our peer group.
  Sustaining growth and shareholder return
Growth is at the heart of our strategic priorities.
A strong pipeline of projects and investment opportunities will enable us to achieve our ambitious short and long-term growth targets.
Over the next four years, we will invest euro 44.6 billion in our businesses to ensure our continued growth, also beyond 2010. This investment program, the largest ever in Eni’s history, will be carried out with tight financial discipline.
The projected free cash flow in 2010 will allow us to sustain the current flow of dividends in real terms, even with a scenario of 40 $/bl Brent.

Among Eni’s business divisions, EXPLORATION & PRODUCTION showed the strongest growth.
In 2006, the division’s adjusted net profit increased by 17.7% to euro 7.3 billion. Oil and gas production rose by approximately 2% to 1.77 million boepd.
This increase was entirely organic and was achieved despite the negative impact of the unilateral termination of the Dación contract in Venezuela and the adverse entitlement effects in PSAs and buyback contracts due to higher oil prices. Excluding the effect of higher oil prices on PSAs and the termination of the Dación contract, organic production growth was close to an impressive 6%. We are committed to maintaining strong organic production growth.
The company targets a production level of 2 million boepd by 2010, with an average growth rate of approximately 3% per year.
Exploration activity reaped substantial results in 2006, reaching an average success rate of 49% and adding 152,000 sq km of net acreage, 99% operated.
Over the medium term, we are committed

 

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Contents

ENI IN 2006 / TO OUR SHAREHOLDERS

to replacing more than 100% of produced reserves.
Development activities are progressing in many fields around the world, including Kashagan, where we expect higher capex and a longer timetable. However, we have also been able to confirm that the field is capable of higher production levels than previously thought.

We are progressing with the global expansion of the LNG business as a way to monetize our large gas reserve base. Major steps taken in 2006 include the start-up of train five at the Bonny liquefaction plant in Nigeria, where a sixth train will commence operations in 2008, and the signing of a framework agreement for doubling the capacity of the Damietta liquefaction plant in Egypt by 2010.
The growth options we are presently pursuing with our partner Gazprom could potentially enable us to accelerate the achievement of our growth targets.

In GAS & POWER, our strong and integrated position in Europe generates stable and robust earnings and cash flows. Adjusted net profit for the year rose by 12.1% to euro 2.9 billion, supported by an approximately 16% increase in volumes sold in Europe (excluding Italy) to 35 bcm (excluding gas sold by E&P of 4 bcm).
This result was achieved despite stiff competition and mild weather.

Our strategy is based on growing our market share in key European markets, preserving our domestic natural gas business and effectively managing our regulated business. European natural gas demand is forecast to grow steadily in the future, resulting in a cumulative increase of around 45% by 2020 (2.4% per annum).
This, coupled with the decline of Europe’s internal production, means that our continent will become more and more reliant on external supplies to fulfill its gas needs. In this context, Eni is poised to further strengthen its market leadership by leveraging on an unparalleled portfolio of assets in terms of infrastructure, availability of gas – both equity and purchased under long term supply contracts – long-standing relationships with natural gas producing countries, market knowledge and a large customer base. The recent alliance with Gazprom marks a new milestone in our relationship with the largest natural gas producer in the world, and will enable us to reinforce our competitive profile.
By 2010 we are committed to selling more than
  105 bcm of gas worldwide, with sales outside Italy expected to grow at an average rate of 10% per year.

Our REFINING & MARKETING division reported an adjusted net profit of euro 629 million, which was 33.4% lower than in 2005 due to the weak refining margin environment, the appreciation of the euro against the dollar and the impact of higher levels of planned maintenance activity.

Looking forward, several trends are emerging in the refining landscape: the adoption of increasingly strict environmental standards, global imbalances in product availability (especially a deficit of diesel fuel in Europe), a relative abundance of heavy crude and the desire to increase efficiency. These are the key drivers of our strategy.
In Refining, Eni will increase its capital expenditure to enhance the refinery conversion rate in order to meet future product quality requirements, produce higher-value products and chemical feedstocks, lower operating costs and increase refinery flexibility in processing low-quality crude oils. In Marketing, we aim to extract full value from our retail business in Italy through a selective investment program, customer-focused marketing initiatives, effective differentiation of pricing, an improved premium-products offer, and operating efficiencies.

In managing our PETROCHEMICAL operations, which reported an adjusted net profit of euro 174 million for 2006, we remain committed to improving efficiency and selectively developing those plants with sufficient scale and a favorable geographic location.
Capital expenditure will be focussed on implementing de-bottlenecking projects, enhancing the efficiency and flexibility of plants in areas of excellence (styrenes and elastomers) and maintaining high standards of health, safety, security and environmental performance.

In ENGINEERING & CONSTRUCTION, adjusted net profit rose by 22% to euro 400 million, reflecting the strong competitive position held by Saipem, also as a result of the integration of Snamprogetti.
To cope with rising demand for drilling equipment and oilfield services, Saipem is planning to further expand the geographical reach and operational features of its world-class fleet.
Our relentless commitment to technological research and innovation underscores a fundamental belief that technology is key to increasing our competitive

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ENI IN 2006 / TO OUR SHAREHOLDERS

advantage over the long term and promoting sustainable growth. We are conducting research aimed primarily at reducing the costs of finding and recovering hydrocarbons, upgrading heavy oils, monetizing stranded gas and protecting the environment. In particular we are moving forward on our breakthrough technologies: EST (Eni Slurry Technology) for the full exploitation of the heavy barrel, TAP (gas transportation at high pressure) and GTL (gas-to-liquids) for gas monetization.   Sustainable development
2006 marks the first year in which Eni has published a Sustainability Report to communicate more effectively with stakeholders. We now have a more coherent approach to sustainability, and are even more committed to managing and developing your company in a responsible and accountable way. Among the various initiatives, our focus is on reducing greenhouse gas emissions from industrial processes and developing projects to economically exploit flared gas.
In conclusion, 2006 was a very good year for Eni. As well as delivering impressive results, we have worked to create future growth opportunities in all our divisions. We are confident that we can continue to deliver industry-leading growth and superior shareholder returns.

March 29, 2007

In representation of the Board of Directors

Chairman Chief Executive Officer and General Manager

 

 

 

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Contents


Contents

ENI IN 2006 / PROFILE OF THE YEAR

  FINANCIAL HIGHLIGHTS  

2004

 

2005

 

2006

(euro million, unless otherwise specified)  
 
 
Net sales from operations      

57,545

 

73,728

 

86,105

Operating profit      

12,399

 

16,827

 

19,327

Adjusted operating profit      

12,582

 

17,558

 

20,490

Eni's net profit      

7,059

 

8,788

 

9,217

Eni's adjusted net profit      

6,645

 

9,251

 

10,412

Net cash provided by operating activities      

12,500

 

14,936

 

17,001

Capital expenditure      

7,499

 

7,414

 

7,833

Dividends to Eni shareholders relating to the year (a)      

3,384

 

4,086

 

4,594

Cash dividends to Eni shareholders      

2,828

 

5,070

 

4,610

Common stock purchases (gross)      

70

 

1,034

 

1,241

Research and development costs      

257

 

204

 

222

Total assets at year end      

72,853

 

83,850

 

88,312

Total debt at year end      

12,684

 

12,998

 

11,699

Shareholders’ equity including minority interest at year end      

35,540

 

39,217

 

41,199

Net borrowings at year end      

10,443

 

10,475

 

6,767

Net capital employed at year end      

45,983

 

49,692

 

47,966

Return On Average Capital Employed (ROACE)   

  

  

  

  

  

  

  

- reported  

(%)

 

16.6

 

19.5

 

20.3

- adjusted  

(%)

 

15.9

 

20.5

 

22.7

Leverage       0.29   0.27   0.16
   
 
 
     
(a)   Amounts due on the payment of the balance of 2006 dividend are estimated.

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ENI IN 2006 / PROFILE OF THE YEAR

  SHAREHOLDER INFORMATION  

2004

 

2005

 

2006

   
 
 
Eni's net profit:                  
- per share (a)  

(euro)

 

1.87

 

2.34

 

2.49

 
- per ADR (b)  

(US$)

 

4.66

 

5.81

 

6.26

 
Eni's adjusted net profit:                  
- per share (a)  

(euro)

 

1.76

 

2.46

 

2.81

 
- per ADR (b)  

(US$)

 

4.38

 

6.12

 

7.07

 
Dividend pertaining to the year:                  
- per share  

(euro)

 

0.90

 

1.10

 

1.25

 
- per ADR (b)  

(US$)

 

2.24

 

2.74

 

3.14

 
Annual dividend per share growth  

(%)

 

20.0

 

22.2

 

13.6

 
Pay-out  

(%)

 

48

 

46

 

50

 
Dividend yield (c)  

(%)

 

4.9

 

4.7

 

5.0

 
Share price at year end  

(euro)

 

18.42

 

23.43

 

25.48

 
Cash dividend to net profit  

(%)

 

40

 

58

 

50

 
Cash dividend to Free Cash Flow (FCF)  

(%)

 

45

 

62

 

47

 
Total shareholder return (TSR)  

(%)

 

28.5

 

35.3

 

14.8

 
Number of shares outstanding:                  
- at year end  

(million)

 

3,770.0

 

3,727.3

 

3,680.4

 
- average (fully diluted)  

(million)

 

3,774.9

 

3,763.4

 

3,701.3

 
Market capitalization (d)  

(euro billion)

 

69.4

 

87.3

 

93.8

 
Market quotations for common stock on the Mercato Telematico Azionario (MTA - "Telematico")                  
High  

(euro)

 

18.75

 

24.96

 

25.73

 
Low  

(euro)

 

14.72

 

17.93

 

21.82

 
Average daily close  

(euro)

 

16.94

 

21.60

 

23.83

 
Year-end close  

(euro)

 

18.42

 

23.43

 

25.48

 
Market quotations for ADR on the New York Stock Exchange (e)                  
High  

(US$)

 

126.45

 

151.35

 

67.69

 
Low  

(US$)

 

92.35

 

118.50

 

54.65

 
Average daily close  

(US$)

 

105.60

 

134.02

 

59.97

 
Year-end close  

(US$)

 

125.84

 

139.46

 

67.28

 
Average daily traded volumes  

(million of shares)

 

20.0

 

28.5

 

26.2

 
Value  

(euro million)

 

338.7

 

620.7

 

619.1

 
   
 
 
     
(a)   Fully diluted. Ratio of net profit and average number of shares outstanding in the year. Dollar amounts are converted on the basis of the average EUR/USD exchange rate quoted by the ECB for the periods presented.
(b)   One ADR (American Depositary Receipt) is equal to two Eni ordinary shares.
(c)   Ratio of dividend for the period and average price of Eni shares in December.
(d)   Number of outstanding shares by references price at year end.
(e)   Effective January 10, 2006 a 5:2 stock split was made.

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ENI IN 2006 / PROFILE OF THE YEAR

The Eni share

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ENI IN 2006 / PROFILE OF THE YEAR

  VOLUMES SUMMARY  

2004

 

2005

 

2006

             
Exploration & Production                
Net proved reserves of hydrocarbons (at 31 December)  

(mmboe)

 

7,218

 

6,837

 

6,436

- Liquids  

(mmbbl)

 

4,008

 

3,773

 

3,481

- Natural gas  

(bcf)

 

18,435

 

17,591

 

16,965

Average reserve life index  

(year)

 

12.1

 

10.8

 

10.0

Production of hydrocarbons  

(kboe/d)

 

1,624

 

1,737

 

1,770

- Liquids  

(kbbl/d)

 

1,034

 

1,111

 

1,079

- Natural gas  

(mmcf/d)

 

3,387

 

3,595

 

3,966

Gas & Power                
Worldwide gas sales  

(bcm)

 

87.03

 

94.21

 

97.48

Total gas sales in Europe  

(bcm)

 

85.32

 

92.50

 

95.97

- G&P division sales  

(bcm)

 

80.62

 

87.99

 

91.90

- Upstream sales (a)  

(bcm)

 

4.70

 

4.51

 

4.07

Customers in Italy  

(million)

 

5.95

 

6.02

 

6.54

Gas volumes transported in Italy  

(bcm)

 

80.41

 

85.10

 

87.99

Electricity production sold  

(TWh)

 

13.85

 

22.77

 

24.82

Refining & Marketing                
Refining throughputs on own account  

(mmtonnes)

 

37.69

 

38.79

 

38.04

Refining throughputs of wholly-owned refineries  

(mmtonnes)

 

26.75

 

27.34

 

27.17

Balanced capacity of wholly-owned refineries  

(kbbl/d)

 

504

 

524

 

534

Balanced capacity utilization rate  

(%)

 

100

 

100

 

100

Sales of petroleum products on Agip branded network in Europe  

(mmtonnes)

 

12.35

 

12.42

 

12.48

Agip branded service stations in Europe at period end  

(units)

 

6,225

 

6,282

 

6,294

Average throughput of Agip branded network in Europe  

(kliters/y)

 

2,488

 

2,479

 

2,470

Engineering & Construction                
Orders acquired  

(euro million)

 

5,784

 

8,395

 

11,172

Order backlog at period end  

(euro million)

 

8,521

 

10,122

 

13,191

Employees at period end  

(units)

 

70,348

 

72,258

 

73,572

     
(a)   Does not include Eni’s share of Nigerian LNG (Eni 10.4%) sales in Europe amounting to 1.30; 1.31; 1.55 bcm; in 2004, 2005 and 2006, respectively.

 

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ENI IN 2006 / PROFILE OF THE YEAR

Eni at a glance

Eni is a major integrated energy company, committed to growth in the activities of finding, producing, transporting, transforming and marketing oil and gas.

In Exploration & Production, Eni boasts strong positions in some of the fastest growing oil and gas basins in the world such as the Caspian Region, North and West Africa. The quality of our assets, long-standing relationships with key host countries, and a strong pipeline of capital projects and investment opportunities will enable Eni to deliver industry-leading growth in both the short and the long term.

Eni Gas & Power division covers all phases of the gas value chain: supply, transport, distribution and marketing, resulting in a fully integrated business model. A significant installed power generation capacity enables Eni to extract further value from gas, diversifying its commercial outlets. The main feature of the Gas & Power division is its ability to generate a steady stream of earnings and cash flow, leveraging on its unparalleled asset base. Eni boasts market leadership in Europe owing to a unique competitive position thanks to gas availability under long-term supply contracts and equity gas, access to infrastructure, long-term relationships with key producing countries, market knowledge and a wide portfolio of clients. These assets provide Eni with a solid platform for growth. Integration with upstream operations provides the Group with the ability to monetize its equity gas reserves and to pursue opportunities arising in the gas market.

Eni is leader in the refining business and in the marketing of refined products in Italy and holds solid positions in the marketing of refined products in selected European countries. Eni’s refining and marketing operations are efficiently integrated valuable logistic assets, so as to maximize cost efficiencies and deliver appreciable returns on capital employed. Integration of Eni refineries with upstream operations further strengthens the competitive position of the Refining & Marketing division.

Its strong presence in engineering and oilfield services provides Eni with the necessary competence and expertise, coupled with access to engineering skills and technologies, to design and execute world scale projects, representing a key element supporting Eni growth and innovation plans.

This business mix is unique among integrated oil and gas companies. The relevant weight of the downstream gas business gives Eni a stable, robust stream of earnings and cash flow, virtually independent of energy price movements, thus counterbalancing the fluctuations of the oil cycle and the higher riskiness of the upstream business.
The same applies to the downstream oil business.

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ENI IN 2006 / PROFILE OF THE YEAR

Eni’s key objectives are to deliver superior growth and attractive shareholder returns over the long term.
Eni’s strategy is consistent with these goals and is based on the following guidelines:
- leverage on its asset portfolio and execution capabilities;
- allocate the cash generated from operations to capital expenditure, driving long-term organic growth, and to an attractive and sustainable flow of dividends;
- use cash in excess of capital expenditure and dividend needs to continue the programme of share repurchase and to maintain a solid financial structure;
- apply tight financial discipline to investment decisions;
- continue to improve operating efficiency and effectiveness;
- manage risks;
- devote significant resources to technological innovation in order to create and maintain competitive advantages;
- promote the sustainability of the business model.

Over the next four years, Eni will implement the largest capital expenditure program in its history by investing euro 44.6 billion in its businesses to support continued growth, also beyond 2010. The ability to generate robust cash flow from operations will enable Eni to finance its capital expenditure plans and to sustain the distribution of dividends to shareholders.
Since 2000, we have returned approximately euro 27 billion to our shareholders through dividends and repurchase of own shares. Of that, approximately 80% has been distributed to shareholders via dividends, which have been hiked by an impressive 200% over this period. At the same time, we invested approximately euro 66 billion in capital expenditure and acquisitions in order to boost growth in all our businesses, achieving in particular a 50% increase in daily oil and gas production (or a compound annual growth rate of approximately 7%). Meanwhile, we have managed to maintain a healthy balance sheet thanks to our impressive cash flow generation, totaling euro 85 billion; a further euro 7 billion was generated by divesting non strategic assets and businesses. Finally, thanks to the repurchase of our own shares, we have reduced the number of shares outstanding by approximately 8%, boosting earnings per share by the same amount.

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Development of the Kashagan field offshore Kazakhstan. Pictured above is a floating production hub for collecting oil and natural gas from artificial satellite islands. After an early stage treatment, oil is transported onshore for further purification and exportation.

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

15,346

 

22,531

 

27,173

Operating profit      

8,185

 

12,592

 

15,580

Adjusted operating profit      

8,202

 

12,903

 

15,763

Adjusted net profit      

4,033

 

6,186

 

7,279

Capital expenditure      

4,853

 

4,965

 

5,203

of which: exploration (b)      

499

 

656

 

1,348

Capital employed, net      

17,937

 

20,206

 

18,590

ROACE adjusted  

(%)

 

22.7

 

32.4

 

37.5

Average realizations                
- Liquids  

($/bbl)

 

34.73

 

49.09

 

60.09

- Natural gas  

($/mmcf)

 

3.89

 

4.49

 

5.29

- Total hydrocarbons  

($/boe)

 

30.40

 

41.06

 

48.87

Production                
- Liquids  

(kbbl/d)

 

1,034

 

1,111

 

1,079

- Natural gas  

(mmcf/d)

 

3,387

 

3,595

 

3,966

- Total hydrocarbons  

(kboe/d)

 

1,624

 

1,737

 

1,770

Net proved reserves                
- Liquids  

(mmbbl)

 

4,008

 

3,773

 

3,481

- Natural gas  

(bcf)

 

18,435

 

17,591

 

16,965

- Total hydrocarbons  

(mmboe)

 

7,218

 

6,837

 

6,436

Reserve life index  

(year)

 

12.1

 

10.8

 

10.0

Proved reserve replacement ratio  

(%)

 

105

 

23

 

65

Employees at year end  

(unit)

 

7,477

 

8,030

 

8,336

       
 
 
     
(a)   Before elimination of intersegment sales.
(b)   Includes exploration bonus.

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ENI IN 2006 / EXPLORATION & PRODUCTION

STRATEGIES

In Exploration & Production, Eni boasts strong positions in some of the fastest growing oil and gas basins in the world such
as the Caspian Region, North and West Africa. The quality of our assets, long-standing relationships with key host countries,
and a strong pipeline of capital projects and investment opportunities will enable Eni to deliver industry-leading growth in both the short and the long term. Consistent with this goal, strategies for our global exploration, development and production operations have remained basically unchanged for many years to date and feature as follows:

  • Maintain strong production growth;
  • Ensure medium to long-term business sustainability by focusing on reserve replacement;
  • Develop new projects to fuel future growth; and
  • Develop the LNG business.

In order to carry out these fundamental strategies, Eni intends to invest approximately euro 30.6 billion addressed to exploration initiatives and reserve development over the next four-year period frame.

2006 HIGHLIGHTS

In February 2007, Eni purchased exploration and production onshore activities operated by Maurel & Prom in Congo, entailing a cash consideration of $1.4 billion. This deal is consistent with Eni’s strategy of purchasing proved and unproved reserves and producing assets in legacy countries where Eni can achieve synergies leveraging on own competencies and the availability of facilities. This transaction is subject to approval by the Congolese authorities.

In 2006 adjusted net profit was euro 7,279 million, up euro 1,093 million from a year ago (+17.7%), reflecting a better operating profit as a result of higher oil and natural gas realization in dollars combined with increased production volumes sold. These positives were offset in part by higher operating costs and a high adjusted tax rate.

Return on average capital employed calculated on an adjusted basis was 37.5% in 2006, higher than in 2005 (32.4%).

Oil and natural gas production for the year averaged 1.77 mmboe/d, up 1.9% from 2005. This included the loss of production at the Venezuelan Dación oilfield and lower entitlements in certain Production Sharing Agreements (PSAs) and buy-back contracts due to higher oil and gas prices. Eni delivered its 3% production growth rate based on a $55 per barrel scenario, as announced in the 2006 quarterly production outlook.

 

Net proved reserves at December 31, 2006 stood at 6.44 bboe (down 6% compared with December 31, 2005), representing 10 years of remaining production at the current rate. Organic proved additions, as calculated by applying a year-end Brent price of $58.925 per barrel, replaced 65% of production. Assuming Brent is constant at $40 per barrel when determining entitlements in PSAs, the three-year average proved reserve replacement ratio would be 106%.

Eni invested euro 3.6 billion in the development of oil and natural gas reserves, in particular in Kazakhstan, Angola, Egypt and Italy. In exploration activities Eni invested euro 1.4 billion (up 106% compared with 2005) to support reserve replacement and the renewal of its portfolio.

In 2006, Eni achieved several hydrocarbon discoveries, mainly in Indonesia, Egypt, Kazakhstan, Norway, Nigeria, the United Kingdom, the Gulf of Mexico, Italy, Angola and Congo. A total of 68 exploratory wells were completed (35.9 net to Eni), with a commercial rate of success of 43% (49% net to Eni). A further 26 wells were in progress as of the year-end.

Eni’s exploratory portfolio was strengthened through acquisition of assets in both core areas such as Angola, Alaska, Brazil, Congo, Egypt, Nigeria, Norway, Pakistan, the Gulf of Mexico and new countries/areas with high mineral potential such as Mali, Mozambique and East Timor. Gross acquired acreage extends for approximately 259,000 square kilometers (152,000 net to Eni, 99% operated).

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Algeria, the principal producing fields operated by Eni are located in the Bir Rebaa area in the South-Eastern desert.

Maintain strong production growth
Eni’s strategy is to build on its strong position in some of the world’s most attractive oil and gas basins to deliver industry leading production growth. We plan to accomplish this by applying the most cost-effective technologies and operations management systems to each and every asset to maximize the commercial recovery of hydrocarbons.

Eni’s assets are well balanced between mature producing fields and fields that are at the early stages of their producing cycles with significant opportunities for growth. Mature areas include mainland and offshore Italy, the North Sea and certain basins in Egypt. Growing areas include Libya, offshore and onshore West Africa, the Caspian Sea and the Nile Delta. Eni expects contributions from the latter to boost production growth to 2010 and beyond.
  Eni continually invests in its existing asset base to increase resource recovery, maximize profitability, and extend field life. New production volumes are generated through workovers, drilling of new wells, and projectimplementation. In 2006, Eni invested euro 3.6 billion to develop new reserves and to maximize resource recovery from existing fields. In the next four years, Eni plans to invest approximately euro 22.5 billion evenly allocatedto initiatives intended to counteract mature field decline, fuel medium-term growth and support growth beyond 2010.

Several fields/projects were started up during 2006. Among the key start-ups are: (i) the Benguela/Belize and Lobito/Tomboco fields in Block 14 (Eni’s interest 20%), holding recoverable reserves of approximately 460 mmbbl. Peak production at 158 kbbl/d (20 net to Eni) is expected in 2009 upon completion of the drilling

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program; (ii) the fifth train as a part of the development of the Bonny liquefaction plant (Eni’s interest 10.4%) in Nigeria, increasing plant capacity to 17 mmtonnes/y of LNG (812 bcf/y of feed gas); (iii) the gas phase of the Bayu-Undan field (Eni’s interest 12.04%) in Australia, starting supplies to the Darwin plant with liquefaction capacity of 3.5 mmtonnes/y of LNG. Peak production at 160 kboe/d (18 net to Eni) is expected in 2008.

PRODUCTION VOLUMES OUTLOOK
In 2006, oil and gas production averaged 1,770 kboe/d, up 33 kboe from 2005 or 1.9%, despite; (i) the impact of the loss of production at the Dación oil field in Venezuela (down 46 kboe/d) as a consequence of the unilateral cancellation of the relevant service contract by the Venezuelan state oil company PDVSA; and (ii) adverse entitlement effects (down 21 kboe/d) in PSAs and buy-back contracts due to higher oil prices. Production growth was driven by a remarkable increase in gas production mainly in Libya, Egypt, Nigeria, Australia and Croatia; oil production increased in Angola and Libya. Organic growth was partially offset by mature field

  declines and production outages in Nigeria due to social unrest. The share of production outside Italy was 87% (85% in 2005).
In the medium term, Eni expects to deliver a 3% compound average growth rate from 2007 to 2010, targeting a production level in excess of 2 mmboe/d by 2010. In subsequent years and up to 2013, Eni projects an annual growth rate of 3%. This goal will be achieved entirely through organic growth mainly in our key producing basins of North and West Africa and the Caspian region, leveraging on Eni’s unique position and solid relationships with many of the fastest growing producing countries in the world and on its strong pipeline of capital projects and investment opportunities. In greater detail, production growth will be fed by means of:
  • developing LNG projects, aiming at monetizing our large gas reserve base;
  • starting up new fields, some of which already under execution and other waiting for finalization of exploratory and appraisal activities;
  • leveraging on our long life fields, including Karachaganak in Kazakhstan, the Western Libyan Gas project, Val d’Agri in Italy, Ekofisk and Aasgard offshore Norway, Belayim and Port Fouad in Egypt, and, in perspective, our massive Kashagan field;
  • optimizing reserve recovery from declining fields.

Eni’s future production profiles are based on a long-term Brent price assumption of 40 $/bbl in real terms. Actual production volumes will vary from year to year due to the timing of individual project start-ups, operational outages, reservoir performance, regulatory changes, asset sales, severe weather events, price effects under production sharing contracts, and other factors.

Val d’Agri field Southern Italy. Producing since 1999, Val d’Agri exemplifies a long-life field within Eni’s asset portfolio. In 2006 this field produced 82 kboe/d net to Eni on average, and is expected to deliver a solid production plateau over the next several years thanks to continued development.

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Ensure medium to long-term business sustainability by focusing on reserve replacement
Eni intends to pay special attention to reserve replacement in order to ensure the medium to long-term sustainability of its business. In pursuing this goal, Eni intends to:
  • optimize its portfolio of development properties by focusing on core areas, seeking new opportunities and divesting marginal assets;
  • pursue new exploration opportunities targeting a sound balance between high risk/high reward initiatives and established/mature projects.

As of December 31, 2006, Eni’s portfolio of mineral rights consisted of 1,029 exclusive or shared rights for exploration and development in 36 countries on five continents for a total net acreage of 385,219 square kilometers. Of these, 48,273 square kilometers concerned production and development. This geographically and geologically diverse, high-quality portfolio balances risks and rewards to deliver both near-term and long-term production growth.

In the medium term, Eni expects to more than replace produced reserves through organic additions. Eni’s reserve replacement ratio will be supported by the high mineral potential of our assets located in core areas such as the Caspian Sea, West and North Africa.

  GROWING THE RESOURCE BASE
The success of Eni’s approach is demonstrated by its ability in replacing produced reserves. Between 2003 and 2006, exploration reserves discovered were approximately 700 mmboe on average a year for a cumulative amount of 2.8 bboe, higher than our cumulative production over the same period.
Positive contributions came from both legacy countries such as Nigeria, Angola, Egypt and Kazakhstan and new frontier areas such as the Barents Sea and the ultra-deep waters of the Gulf of Mexico.
At 25 bboe, our solid resource base will secure 38 years of production at current rates.
Under SEC reporting standards, proved reserves at 2006 year-end were 6.4 billion boe, representing a life index of 10 years. In the 2004-2006 period, considering adverse entitlement impacts in certain PSAs and buy-back contracts resulting from higher oil prices and assuming Brent constant at $40 per barrel when determining entitlements in PSAs, we would have replaced on average 106% of production through organic additions. On the other hand, contractual terms of PSAs providing for a cost oil with a favorable cap, while affecting the reported reserve replacement ratio, allow a strong acceleration of investment recovery under a higher price environment, thus enabling a reduction in payout time and a significant improvement in the rate of return of relevant projects.
For 2006 only, by applying the year-end price of 58.925 $/bbl, organic additions for the year came in at 417 mmboe with a reserve replacement ratio of 65%.

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EXPLORATION OPPORTUNITIES
Exploration activities will play a crucial role in enlarging Eni’s resource base in order to fuel new production, and in securing access to new opportunities. In light of this, management will devote a great deal of focus and effort to exploration. In 2006, Eni more than doubled its investment in exploration from the previous year, resulting in a total of 68 wells drilled with an SEC exploration success of 43%, and approximately 152,000 square kilometers of new acreage acquired. In the next four years, management plans to invest on average approximately euro 1.1 billion per year in exploration activities, resulting in a cumulative euro 4.4 billion that is substantially higher (+51%) than the previous four-year plan (2006-2009). The cornerstones of Eni’s exploration strategy are:
  • selectively assess opportunities to enhance the competitiveness of Eni’s full-cycle production costs;
  • concentrate resources in core areas: approximately 70% of planned investment will be directed to 10 countries;
  • exploit the full mineral potential of recently acquired areas;
  • complete portfolio renewal.

In 2006, as part of its exploration strategy, Eni was successful in capturing 12 new opportunities spanning from new, untested exploration plays to well established plays or already-discovered resources, for a total acreage of about 152,000 square kilometers net to Eni, of these 99% as operator. In fact, management intends to concentrate investments in well established areas of presence where availability of production facilities,

  existing competencies and long-term relationships with host countries will enable Eni to readily put in production discovered resources, reducing the time to market and capturing synergies. On the other hand, Eni expects to selectively pursue high risk/high reward opportunities arising from expansion in areas with high mineral potential. Finally, portfolio renewal will be completed, bearing in mind that approximately 70% of total acreage has been renewed over the last three years.

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ENI IN 2006 / EXPLORATION & PRODUCTION

Developing new projects to fuel future growth
Eni has a strong pipeline of development projects that will contribute to the medium and long-term growth of its oil and gas production. Approximately 20 of these projects are among the top 100 projects worldwide.
Eni expects an evolution in the type of oil and gas resources from which it will be producing and in the physical conditions in which it will be operating. Many new developments will be located in more challenging
  environments, continuing to require innovations in technology. Our new long life projects, integrated LNG projects and new start ups will boost Eni production growth over the medium and long term. Overall, start ups expected in future years will add approximately 450 kboe/d to 2010 production and 700 kboe/d to 2013 production. New production will come from both legacy countries and new regions as well as from mature basins and new high potential ones.

EIGHT MAJOR PROJECTS

Mondo Block 15 - Angola (Eni 20%)
The Mondo deepwater oil field contains gross recoverable reserves of 278 mmbbl. Recovery of oil will be achieved with the installation of an FPSO vessel with a treatment capacity of 100 kbbl/d. Production is expected to start in the first quarter 2008, peaking at 18 kbbl/d net to Eni in 2009.

Saxi/Batuque Block 15 -Angola (Eni 20%)
The Saxi/Batuque deepwater oil field contains gross recoverable reserves of 305 mmbbl. Recovery of oil will be achieved with the installation of an FPSO vessel with a treatment capacity of 100 kbbl/d. Production is expected to start in the second quarter 2008, peaking at 18 kbbl/d net to Eni in 2009.
 

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Landana-Tombua Block 14 - Angola (Eni 20%)
The Landana and Tombua deepwater oil fields contain gross recoverable reserves of 322 mmbbl. The development project’s scope includes installation of a Compliant Piled Tower (CPT) with a capacity of 120,000 bbl/d and linkage of a part of producing wells to existing facilities at the nearby Benguela/Belize fields. Production is expected to peak at 130 kbbl/d (23 net to Eni) in 2010 upon completion of the drilling program. In 2006, a single well started production through facilities in place as outlined.
 

 

Blacktip Block WA-279-P - Australia (Eni 100% Op.)
The offshore Blacktip gas and liquids field contains gross recoverable reserves of 140 mmbbl and is located in the Bonaparte basin at a water depth of 50 meters about 100 kilometers off the north-western Australian coast. Gas production is expected to be transferred to a
  treatment plant onshore with a capacity of 46 bcf/y.
Start-up is expected at the beginning of 2009. Under a 25-year agreement signed with Darwin Power & Water Utility Co, a total amount of 706 bcf of natural gas is expected to be supplied with an option for further volume increases.

El Merk Synergy project - Algeria
Leveraging on expected synergies with the development of reserves in Block 208, 212, 405a and 404, this project provides for the construction of a central production facility which will produce stabilized oil, condensates and NGL with an initial production level of at 144 kboe/d (19 net to Eni) in 2010. In 2006, 85% of basic engineering work was completed.
 

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Karachaganak - Kazakhstan (Eni 32.5% Co-op.)
This large liquid and gas field located onshore Kazakhstan holds recoverable reserves of 3.6 bboe. It represents an example of a long life field. Liquid production is treated at the Karachaganak Processing Complex with a capacity of 150 kboe/d. Two-thirds of liquid volumes are exported to western markets via pipeline; residual liquid and gas volumes are sold on local Russian markets. In 2006, production of this field net to Eni was 103 kboe/d. Development activities planned aim at maintaining current liquid production plateau. In 2006 upgrading of liquid treatment facilities was sanctioned envisaging the construction of a fourth unit. Such new capacity is expected to increase the export of production volumes which were previously marketed on local Russian markets, resulting in an enhancement of price realizations. In addition, management is evaluating the development of gas reserves by means of finalizing relevant sale contracts with Kazakh and Russian companies, also entailing, if contracts are finalized, the construction of a gas treatment plant.

Kashagan - Kazakhstan (Eni 18.5% Op.)
The development plan of the massive Kashagan oil field, considered the most important discovery of the past thirty years, to be implemented in three phases, aims at producing up to 13 billion barrels of recoverable reserves also by means of partial gas reinjection.
The development of the field provides for the construction of platforms and artificial islands (hubs) which will collect production from satellite islands.
Oil and non reinjected gas will be treated in the hubs and delivered, through two separate lines, to onshore treatment plants (located at Bolashak, near Atyrau).
The oil will be further stabilized and purified; natural gas will be treated for the removal of hydrogen sulphide and

  will be mostly used as fuel for the production plants.
The remaining amounts will be marketed.
Production start-up is currently scheduled for the third quarter of 2010 as compared to an initial forecast indicating a start-up in 2008, due also to the need on part of Eni to perform certain studies to define measures intended to enhance the overall level of safety and operability of facilities. As a result of said reconfiguration completed by year-end, the onshore design has been confirmed, while certain enhancements have been identified offshore which do not alter the original development concept. These enhancements are expected to be included in the development plan and implemented. Estimated capital expenditure to reach the 300 kbbl/d production level targeted in the first development phase stands currently at $19 billion, representing a remarkable increase over the approved budget of $10.3 billion in real terms 2007, sanctioned in 2004. This cost increase was driven by: (i) a cost increase of materials and services driven by sector-specific inflation and a negative impact due to a weakening US dollar; (ii) an underestimation of costs to conduct offshore operations in shallow/ultra shallow waters where the Kashagan field is located due to a lack of benchmarks, also reflecting technical and logistic issues and environmental constraints; (iii) the enhancements to the original layout of offshore facilities. Based on the high level of productivity yielded by the first three development wells, management currently expects a full field production plateau of 1.5 mmboe/d, representing a 25% increase from the original target envisaged by the development plan. In addition, over

 

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the long term management expects to exploit the huge mineral potential of Kashagan satellite discoveries, including Kalamkas and Kairan, which are currently undergoing an intense appraisal campaign.
To date this campaign has resulted in a 100% success rate, fostering high expectations on future developments of Kashagan satellites.
The Consortium is currently assessing various options to export production to international markets, including: (i) use of existing infrastructure, such as the Caspian Pipeline Consortium pipeline and the Atyrau-Samara pipeline; and (ii) construction of new infrastructure.
The latter comprises both laying a pipeline connecting the Kashagan production center at Bolashak to the Baku-Tbilisi-Cehyan pipeline (BTC-Eni’s interest 5%, corresponding to the right to transport up to 50 kbbl/d), and construction of a pipeline designed to bypass the Turkish Straits of Bosphorus and Dardanelles, enabling delivery of oil produced in the Caspian region to the Ceyhan commercial hub on the Mediterranean coast.
  This new infrastructure is expected to be 550-kilometers long with a maximum transport capacity of 1.5 mmbbl/d of oil, corresponding to approximately 75 mmtonnes/y, and will represent a more efficient and environment-friendly alternative compared to the option of transporting oil by ship through the Turkish Straits of Bosphorus and Dardanelles. Following award of the relevant license to the Turkish company Çalik Enerji, partnering Eni in this initiative (both with a 50% stake), engineering activities started in the second half of 2006.

Taurt - Egypt (Eni 50%)
The offshore Taurt gas field contains gross recoverable reserves of 930 bcf and is located in the Nile Delta at a water depth of 105 meters. The development plan provides for the drilling of seven wells which are expected to be linked to existing onshore treatment facilities at West Harbour. Production plateau is targeted at 46 mmcf/d net to Eni, in 2008.

Libya - Mellitah treatment plant. The Western Libyan Gas Project is the first major project to valorize the natural gas produced in Libya through export to and marketing in Europe. Production from Bahr Essalam and Wafa fields is processed at the onshore Mellitah plant.

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Develop in LNG
Eni operates its gas business as an integrated portfolio in order to fully extract value from the gas chain and monetize its large gas reserves. Liquefied Natural Gas is a key part of this strategy. Eni intends to build a global LNG business, aiming at:
  • exploiting gas equity availability in order to supply the attractive markets of Europe and North America;
  • growing LNG production in areas with high potential and low producing costs;
  • purchasing interests in liquefaction plants in order to support development of the LNG business.
  Net liquefaction capacity in 2006 was 321 bcf, mainly concentrated in Nigeria and Egypt, and is expected to expand to 343 bcf in 2010 and in excess of 509 bcf in 2012 by means of developing capacity at the Bonny liquefaction plant, building the new Brass plant in Nigeria, and implementing the expansion plan of the Damietta LNG plant in Egypt.
LNG sales are expected to grow from 127 bcf in 2006 to166 bcf in 2010; equity gas supplies to LNG plants of 162 bcf in 2006 are expected to increase up to 233 bcf in 2010.

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Three major LNG projects
Brass LNG - Nigeria (Eni 17%)
Eni holds a 17% interest in Brass LNG Ltd which will implement building plans of a liquefaction plant near the existing Brass oil terminal (Eni’s interest 20%) on the Nigerian coast. This plant is expected to start operations in 2011 at an initial treatment capacity of 487 bcf/y on two trains, corresponding to a production of 10 million tonnes/y of LNG. Supplies to this plant will come from associated gas of nearby producing fields and through development of gas reserves of Blocks OML 60 and 61 (Eni operator with a 20% interest). When fully operational, equity gas volumes supplied to this plant will reach 170 mmcf/d (30 kboe/d).

Nigeria. An aerial view of the Bonny liquefaction plant.

Damietta LNG - Egypt (Eni 40%)
As part of the expansion plan of the Damietta LNG plant, in June 2006, Eni and its partners signed a framework agreement for doubling the capacity of the Damietta liquefaction plant by means of a second treatment unit with a capacity of 268 bcf/y of gas, corresponding to production of approximately 5 mmtonnes/y of LNG for a twenty-year period starting in 2010. This project is expected to support the ramp-up of Eni’s natural gas production in the Nile Delta, targeting supplies of 88 bcf/y. Eni is currently supplying 53 bcf/y to the first unit for a twenty-year period.

 

Bonny LNG 6th & 7th train - Nigeria (Eni 10.4%)
Eni holds a 10.4% interest in the Bonny liquefaction plant located in the eastern part of the Niger Delta. In 2006, a fifth treatment unit started operations, increasing plant capacity to 17 mmtonnes/y of LNG (812 bcf/y of feed gas). A sixth treatment unit with production capacity of 4.1 mmtonnes/y is under construction with expected start-up in 2008; a seventh unit is being engineered. When fully operational, total capacity will hit approximately 30 mmtonnes/y, corresponding to a feed gas of 1,448 bcf/y. Development initiatives for ensuring natural gas supplies to this plant are expected to be deployed in Blocks OML 60, 61, 62 and 63 (Eni’s interest 20%).

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The interconnection point at Gela (Sicily) where the GreenStream gasline carrying gas from Libyan fields links to Eni’s Italian natural gas transport network.
Eni’s unparalleled portfolio of gas assets deeply integrated with upstream operations is a key contributor to Group’s earnings and cash flow.

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

17,302

 

22,969

 

28,368

Operating profit      

3,428

 

3,321

 

3,802

Adjusted operating profit      

3,448

 

3,531

 

3,882

Adjusted net profit      

2,290

 

2,552

 

2,862

Capital expenditure      

1,451

 

1,152

 

1,174

Adjusted capital employed, net      

18,383

 

18,898

 

18,864

ROACE adjusted  

(%)

 

12.6

 

13.7

 

15.1

Worldwide gas sales  

(bcm)

 

87.03

 

94.21

 

97.48

Total gas sales in Europe      

85.32

 

92.50

 

95.97

- G&P division sales      

80.62

 

87.99

 

91.90

- Upstream sales (b)      

4.70

 

4.51

 

4.07

Customers in Italy  

(million units)

 

5.95

 

6.02

 

6.54

Gas volumes transported in Italy  

(bcm)

 

80.41

 

85.10

 

87.99

Electricity production sold  

(terawatthour)

 

13.85

 

22.77

 

24.82

Employees at year end  

(units)

 

12,843

 

12,324

 

12,074

       
 
 
     
(a)   Before elimination of intersegment sales.
(b)   Does not included Eni’s share of sales made by Nigeria LNG (Eni’s share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006 respectively.

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ENI IN 2006 / GAS & POWER

STRATEGIES

Eni’s Gas & Power division covers all phases of the gas value chain: supply, transport, distribution and marketing, resulting in a fully integrated business model. A significant installed power generation capacity enables Eni to extract further value from gas, diversifying its commercial outlets. The main feature of the Gas & Power division is its ability to generate a steady stream of earnings and cash flow leveraging on its unparalleled asset base. Eni boasts market leadership in Europe owing to a unique competitive position thanks to
  gas availability under long-term supply contracts and equity gas, access to infrastructure, long-term relationships with key producing countries, market knowledge and a wide portfolio of clients. These assets provide Eni with a solid platform for growth. Integration with upstream operations provides the Group with the ability to monetize its equity gas reserves and to pursue opportunities arising in the gas market.
Eni’s key target for its Gas & Power division is to generate free cash flow1 of euro 2.1 billion in 2010, resulting in a 3% average growth rate from 2006.
The strategic guidelines to attain this target are as follows:

 

 
  • Grow international sales;
  • Maintain strength in domestic market;
  • Effectively manage relationships with strategic suppliers;
  • Increase operational effectiveness; and
  • Develop marketing of LNG aiming also at monetizing equity reserves.

 

2006 HIGHLIGHTS

In November 2006, Eni and Gazprom signed a broad strategic agreement. This agreement strengthens a long term partnership between the two companies and represents a fundamental step towards ensuring the security of energy supplies to Italy. Key features of this deal are the extension of the duration of Gazprom
  gas supply contracts to Eni until 2035, further strengthening Eni’s supply portfolio, and the pursuing of joint initiatives in the upstream sector. Gazprom is expected to enter the Italian market by selling volumes of gas starting in 2007. Gazprom will obtain the availability of such volumes by means of a corresponding reduction in volumes previously supplied to Eni.
     
(1)   Cash flow provided by operating activities less cashoutflows for investing activities.

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ENI IN 2006 / GAS & POWER

In 2006 the Gas & Power business confirmed its ability to generate strong and stable performances. The adjusted net profit rose by euro 310 million to euro 2,862 million from 2005 (up 12.1%) reflecting primarily higher selling margins on natural gas sales, a lower impact of sector specific regulation, and a growth in gas volumes sold.

Operating cash flow stood at euro 3.1 billion, resulting in euro 1.9 billion of free cash flow generation after taking account of capital expenditure requirements and changes in working capital.

Natural gas sales were up approximately 4% to 97.48 bcm driven primarily by a 16% growth in sales in a number of target European markets (mainly in Turkey, Germany/Austria, France) owing also to a build-up of supplies of natural gas from Libya. Volumes decreased in Italy due to mild weather conditions in the fourth quarter of the year.

Electricity production sold was 24.82 TWh, up 9%; installed capacity totalled 4.6 GW at year-end.

Clients served increased by approximately 0.52 million
to 6.54 million.

  Capital expenditure totalled euro 1,174 million and related essentially to development and maintenance of Eni’s transport and distribution networks in Italy, the finalization of the upgrading plan of electricity generation capacity, and the start up of the upgrading plan of import gaslines.

Return on average capital employed was 15.1% in 2006 (13.7% in 2005).

Marketing of natural gas

MARKET POSITION
Eni is leader in the highly attractive European gas sales market, with a market share of around 18% in 2006.
Since the inception of the domestic liberalization process in 2000, Eni has targeted several European consumption areas to pursue growth options beyond its legacy Italian market. This strategy is paying off. Presently, Eni boasts a solid presence in virtually all European markets, including Spain, Germany, Turkey, the United Kingdom, France and Portugal, and is poised to further strengthen its market leadership. In fact, with European natural gas demand forecast to grow steadily in the future, resulting in a cumulative increase of around 45% by 2020 (or 2.4% per annum), and internal production on a declining trend, Europe will increasingly rely upon gas imports to fulfill its gas needs. In such a context, Eni is expected to grow its market share and sales leveraging on its strong competitive position and an unparalleled array of assets in terms of gas availability of both equity gas and purchased gas under long term supply contracts with key producing countries, operating flexibility ensured by an extensive and integrated international transport network, regasification terminals, storage facilities, a large client base, and market knowledge. The recently signed deal with strategic partner Gazprom markedly improves Eni’s competitive profile.

In Italy, despite increasingly stiff competition spurred by the liberalization process and the regulatory activity

 

  ADJUSTED OPERATING PROFIT (million euro)  

2004

 

2005

 

2006

               
Marketing and distribution  

1,827

 

1,777

 

2,062

Transport in Italy  

1,164

 

1,162

 

1,087

Transport outside Italy  

396

 

448

 

579

Power generation  

61

 

144

 

154

   

3,448

 

3,531

 

3,882

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ENI IN 2006 / GAS & POWER

of independent authorities, Eni has managed to preserve its market share and marketing margins and intends to keep on doing the same in the future, leveraging on expected gas demand growth and an enhanced commercial policy. The levers of Eni’s marketing action in Italy will be to focus on most profitable clients, improve the quality of services, deploy a commercial offer tailored on client needs, pursue client loyalty and retention, and finally develop a combined offer of gas and electricity in order to reap the benefits of scale and integration. These actions will be coupled with an intense program to boost operational efficiency, targeting a significant reduction of cost to serve by 2010. Our strong brand recognition, long-standing customer relationships, market understanding and large client base will support our marketing efforts.  

 

  WORLDWIDE GAS SALES (bcm)  

2004

 

2005

 

2006

               
Markets in the rest of Europe   26.84   29.91   34.81
Importers to Italy   10.96   11.53   14.10
Iberian Peninsula   3.59   4.59   5.24
Germany-Austria   3.96   4.23   4.72
Turkey   1.60   2.46   3.68
Hungary-Slovenia-Greece   3.46   3.53   3.26
North Europe   2.93   2.74   2.64
France   0.15   0.65   1.07
Other   0.19   0.18   0.10
Markets extra Europe   1.71   1.71   1.51
Upstream (1)   4.70   4.51   4.07
International gas sales   33.25   36.13   40.39
Italy   53.78   58.08   57.09
             
Worldwide gas sales   87.03   94.21   97.48
     
(1)   Does not include Eni's share of sales made by Nigeria LNG (Eni's share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006, respectively.

 

VOLUMES OUTLOOK
In 2006, Eni’s worldwide gas sales grew approximately 4% to 97.48 bcm, up 3.27 bcm from 2005.
In Italy, in an increasingly competitive environment, gas sales declined 0.99 bcm to 57.09 bcm, down 1.7%, owing also to lower supplies to power generation, wholesalers and residential clients as a result of mild weather conditions in the fourth quarter.
  Gas sales in the rest of Europe rose by approximately 16% to 34.81 bcm, up 4.90 bcm, reflecting increases registered in sales under long-term supply contracts to importers to Italy (up 2.57 bcm), also due to reaching full supplies from Eni’s Libyan fields, and a growth in sales to the Turkish market via the Blue Stream gasline (up 1.22 bcm), and to the Iberian Peninsula, Austro/German and French markets (up 0.65, 0.49, and 0.42 bcm, respectively).

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In the medium term, Eni plans to increase worldwide sales targeting a volume of 105 bcm by 2010, corresponding to a 2.5% average growth rate over the 2007-2010 four-year period. This increase will be driven by an expected 10% average organic growth rate in sales in the rest of Europe to 53.3 bcm. In Italy, Eni expects to sell approximately 50 bcm by 2010, or 46% of the total.
In particular, Eni expects to boost sales in target European markets, leveraging mainly on sale expansion in:
  • Northern Europe, where Eni forecasts an increase of approximately 5.4 bcm reflecting in particular a growth in supplies to spot markets;
 
  • France, where Eni forecasts an increase of approximately 4 bcm reflecting an aggressive policy of building market share, targeting mainly small and mediumsized industrial enterprises;
  • the Iberian Peninsula, where Eni forecasts an increase of approximately 3.3 bcm as a result of expected higher supplies to power generation utilities and
    a growth of Eni’s strategic affiliate Unión Fenosa Gas;
  • Austria/Germany, where Eni forecasts an increase of approximately 2.9 bcm reflecting a growth in business clients; and
  • Turkey, where Eni forecasts an increase of approximately 2.7 bcm owing to the build-up of supplies via the Blue Stream gasline.

 

Supply of gas

In the context of rising gas demand and increasingly tight European markets, Eni enjoys a very strong position owing to an unrivaled supply portfolio and access to a wide-reaching infrastructure network.
Our availability of natural gas is ensured from both equity production from onshore and offshore fields located in Europe (mainland and offshore Italy, the North Sea and offshore Croatia) or in adjacent basins (Libya via gasline and Egypt/Nigeria via LNG), and long term purchase contracts with major producing countries serving Europe, boasting a direct upstream presence in 8 out of 10 of our gas supplying countries. Our diversified supply portfolio insulates us from the
  risk of being heavily dependent on a single source of supplies; in fact, none of Eni’s suppliers weighs for more than 25% in Eni’s current gas needs. In addition, our strong pipeline of LNG projects will further strengthen diversification of Eni’s supplies and integration with upstream operations.
Against this backdrop, the recently signed agreement with strategic partner Gazprom marks a fundamental step in enhancing the security and flexibility of Eni’s gas supplies over the medium and long term. Based on this agreement, the duration of our long-term supply contracts increases from 14 to approximately 23 years and, when these contracts are fully operational in 2010, Eni will be able to purchase approximately 62.4 bcm/y to cope with rising demand.

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ENI IN 2006 / GAS & POWER

Infrastructure

Eni owns the largest European transport and storage infrastructure system, enabling Eni to carry gas from producing countries or its upstream fields to core European markets. Vital to this system are:
  • interests in key pan-European routes carrying natural gas from the production areas of the North Sea and Russia to large Central European markets, as well as in trunklines coming from Algeria and Libyan operated fields. Such lines are linked to the Italian network;
  • an extensive grid of high and medium-pressure trunklines and low-pressure local networks for transport and delivery of gas in its core domestic market to large industrial clients, power generation utilities, and residential and commercial clients;
 
  • interests in certain facilities for the regasification of liquefied natural gas (LNG) located in Italy and Spain to further diversify sources of supplies;
  • availability of a significant storage capacity ensuring the necessary operational flexibility.

In the medium term, Eni plans to invest approximately euro 5.8 billion in order to upgrade both its international and national infrastructure, in view to improve the level of supply diversification and security also to cope with expected growth in demand. A major part of this capital expenditure will be directed to the upgrading of import trunklines from Russia, Algeria and Libya, the national transport and distribution networks, and regasification capacity.

INTERNATIONAL TRANSPORT
Eni’s INTERNATIONAL TRANSPORT system consists of transport rights on an approximately 4,300-kilometer long network of high pressure pipes connecting production areas in Russia, North and West Africa, and the North Sea to Italy, crossing key European markets. Through its 50%-owned Blue Stream, a 774-kilometer long underwater gasline, Eni is able to supply the fast-growing Turkish market.
Eni’s international transport network will undergo a major upgrading plan in order to boost transport capacity of trunklines carrying gas from Algeria, Russia, and Libya; in particular:
  TTPC - The transport capacity of the TTPC gasline from Algeria is expected to be increased by 6.5 bcm/y of which a 3.2 bcm/y portion is planned to come on line on April 1, 2008, and a 3.3 bcm/y portion on October 1, 2008. Capital expenditure is expected at euro 450 million. When the upgrade is fully operational, the gasline will deploy a transport capacity of 33.5 bcm/y. A corresponding capacity on the TMPC downstream gasline is already available. TMPC crosses underwater the Sicily channel.

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TAG - The transport capacity of the TAG gasline from Russia is expected to increase by 6.5 bcm/y coming on line on October 1, 2008. Expected capital expenditure amounts to euro 253 million (Eni’s share is 94%).
When the upgrade is online, the gasline transport capacity will be 44 bcm/y.

GreenStream - Eni plans to upgrade this import gasline from Libya in order to monetize additional reserves of gas. This project targets a 3 bcm/y capacity expansion
  expected to come on line by 2011, with an expenditure of approximately euro 80 million.

Taking into account the full capacity of the GreenStream gasline from Libya currently in place (8 bcm/y), Eni expects to bring on the market approximately 21 bcm/y of new import capacity, when ongoing plans for upgrading the TTPC and TAG gaslines are fully operational in 2009.
This new capacity has been or is being allocated to third parties via open bid procedures.

Turkey; the Blue Stream underwater pipeline, laid at a record depth of over 2,150 meters, links the Russian and Turkish coast of the Black Sea. Started up in 2002, this two-line infrastructure has a transport capacity of 49 mmcm/d. When fully operational in 2010, it will deliver 16 bcm/y (Eni’s share 8 bcm) to the Turkish market.

DOMESTIC TRANSPORT AND DISTRIBUTION
Eni’s DOMESTIC TRANSPORT business is a fully regulated activity with a low risk profile, generating stable earnings and operating cash flow. In fact, transport tariffs and return on capital employed are set by an independent regulator.
Eni’s network extends for 30,889 kilometers covering virtually the entire Italian transport network and comprises high pressure trunklines and medium pressure regional transport networks carrying natural gas from entry points to the system – import lines, storage sites and Italian natural gas fields – to delivery points in correspondence of large industrial complexes, power generation utilities, and local distribution companies serving residential and commercial areas.
In the medium term, Eni plans to upgrade its domestic transport network in order to match transport capacity to the expected increase in import capacity. Due to regulatory mechanisms, these capital projects bear preset rate of returns, thus contributing to reduce the risk profile of Eni’s capital expenditure plan. We also plan to boost earnings of this regulated activity by continued efforts in improving operational efficiency.
  Eni is leader in the Italian natural gas distribution business, counting on the availability of an extensive grid of low pressure gaslines for the delivery of natural gas to approximately 6 million clients in the main urban areas of Italy. Clients include both residential users and small businesses and commercial clients.
In the distribution business, Eni will focus on improving efficiency and reaping economies of scale, while at the same time enhancing the quality of service. As in the case of the transport activity, distribution is a fully regulated business sporting a preset return on capital employed.

LNG

Eni intends to strengthen its integrated LNG business on a global scale, aiming at further diversifying its supply sources, improving operational flexibility, and monetizing its large equity gas reserves. Due to our strong presence in both upstream and downstream operations, we boast a global position in LNG which is well balanced in terms of gas availability, and both liquefaction and regasification capacity. We expect LNG to play an increasingly important role

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in fulfilling worldwide gas requirements, with forecast growth rates in the range of 10% over the medium term.
Eni’s main LNG assets are located in:
  • Italy, where the Panigaglia regasification terminal can input approximately 3.5 bcm/y in the national transport network;
  • Egypt, where Eni has a 40% interest in the Damietta liquefaction plant producing approximately 5 mmtonnes/y of LNG, corresponding to 7.6 bcm/y of feed gas. In June 2006, Eni and its partners signed a framework agreement for doubling the capacity of the plant expected to start operations in 2010-2011;
 
  • Spain, where Eni has a 21.25% interest in the Sagunto plant with a regasification capacity of 6.7 bcm/y and a 9.5% interest in the El Ferrol plant, expected to be completed by the first half of 2007, targeting a regasification capacity of approximately 3.6 bcm/y;
  • USA, where Eni is entitled to a 6 bcm/y share of the initial planned capacity of the Cameron regasification terminal under construction in Louisiana, and expected to start operations in 2008-2009. In order to support supplies to this plant, Eni signed an agreement with Nigeria LNG Limited, operating the Bonny LNG plant in Nigeria, to purchase volumes of LNG equivalent to 2 bcm/y of gas for a twenty-year period. A similar agreement pertaining to 2.3 bcm/y was signed with Brass LNG equivalent, operating a liquefaction terminal under construction in Nigeria.

Power generation

Eni’s natural gas business is integrated downstream with the production of electricity to further extract value from the gas chain. Started in 2000, Eni’s plan for the expansion of its power generation capacity has been substantially completed by the end of 2006, with approximately 90% of the 5.5 gigawatt target new capacity already on stream.
New plants built in existing Eni sites are based on cogeneration, an efficient, environmental-friendly technology that enables low operating costs and lower carbondioxide emissions as compared to other hydrocarbon-based technologies. In 2006, electricity production sold was 24.82 TWh, up 9% over 2005, reflecting the ramp-up of new capacity. In 2010, when target capacity is fully on line, production is expected to reach 30 TWh, corresponding to over 10% of electricity generated in Italy at that date, consuming approximately 6 bcm/year of gas from Eni’s supply portfolio.
 

Ravenna in Northern Italy. A cogeneration unit of the power station. Low CO2 emissions and competitive cost structure are key features of this type of facility, employing the CCGT technology and fired with gas from Eni’s portfolio.

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Following restructuring of its Italian retail operations, Eni’s network currently consists of 4,356 service stations. The majority of these are large-scale, efficient outlets, providing clients a wide range of products and services in addition to fuel.

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)   (million euro)  

26,089

 

33,732

 

38,210

Operating profit      

1,080

 

1,857

 

319

Adjusted operating profit      

923

 

1,214

 

790

Adjusted net profit      

674

 

945

 

629

Capital expenditure      

693

 

656

 

645

Adjusted capital employed, net      

4,835

 

5,326

 

5,766

ROACE adjusted   (%)  

13.0

 

18.2

 

10.7

Refining throughputs on own account   (mmtonnes)  

37.69

 

38.79

 

38.04

Refining throughputs of wholly-owned refineries      

26.75

 

27.34

 

27.17

Balanced capacity of wholly-owned refineries   (kbbl/d)  

504

 

524

 

534

Balanced capacity utilization rate   (%)  

100

 

100

 

100

Retail sales of petroleum products on Agip branded network in Europe   (mmtonnes)  

12.35

 

12.42

 

12.48

Agip branded service stations in Europe at period end   (units)  

6,225

 

6,282

 

6,294

- Italy       4,329   4,394   1,938
- Outside Italy       1,896   1,933   2,470
Average throughput of Agip branded service stations in Europe   (kliters)  

2,488

 

2,479

 

2,470

Employees at year end   (units)  

9,224

 

8,894

 

9,437

       
 
 
     
(a)   Before elimination of intersegment sales.

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ENI IN 2006 / REFINING & MARKETING

STRATEGIES

Eni is leader in the refining business and in the marketing of refined products in Italy and holds solid positions in the marketing of refined products in selected European countries. Eni’s refining and marketing operations are efficiently integrated to maximize cost efficiencies and deliver appreciable returns on capital employed. The integration of Eni refineries with upstream operations further strengthens the competitive positioning of the Refining & Marketing Division.
Eni’s key medium term objective in its downstream oil business is to improve profitability. The strategic guidelines to attain this objective are the following:

In the medium term the implementation of these strategies will be supported by a capital expenditure programme of approximately euro 4.3 billion, focused on upgrading refineries, mainly by increasing primary balanced refining and conversion capacity, and refineries’ flexibility and efficiency, improving logistic assets, and highgrading the network. Management intends to strengthen market leadership in refining in the Mediterranean area, targeting also leadership positions in Europe, and to boost the competitive position of marketing in Italy and in selected European areas.

2006 HIGHLIGHTS

In 2006, adjusted net profit was down euro 316 million to euro 629 million, or 33.4%, mainly due to a decline in refining margins as a result of a weak trading environment.

Eni’s realized refining margins recorded a better trend than market reference margins reflecting Eni’s refinery capacity to process heavy crudes which are discounted as compared to the Brent crude market benchmark, thus resulting in a higher profitability of the heavy barrel.

Return on average capital employed was 10.7% on an adjusted basis, declining from 2005 (18.2% in 2005).

Capital expenditure totaled euro 645 million and mainly related to projects aimed at improving flexibility and yields of refineries and upgrading the retail network in Italy and in the rest of Europe.

Refining throughputs on own account in Italy and outside Italy (38.04 mmtonnes) declined by 0.75 mmtonnes from 2005, down 1.9%, due mainly to lower volumes at third party refineries, while wholly-owned refineries achieved stable processing levels.
 

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Retail sales of refined products in Italy (8.66 mmtonnes) declined 1% from 2005 mainly due to competitive pressure. This decrease was more than offset by a growth in retail volumes marketed in the rest of Europe (3.82 mmtonnes, up 4.1%), mainly in Germany and Spain.

Sales on the wholesale market in Italy (10.06 mmtonnes) were down 4% reflecting primarily the impact of mild weather conditions in the fourth quarter. This decline was partially offset by a growth in volumes marketed on wholesale markets in the rest of Europe (4.6 mmtonnes, up 2.2%), in particular in Germany and Spain.

Refining

Eni is leader in the refining business in Italy.
Eni owns five refineries in Italy and a 50% interest in the Milazzo refinery, in Sicily, and interests in refineries in Germany and the Czech Republic with a total refining capacity (balanced with conversion capacity1) of approximately 35.5 mmtonnes (equal to 710 bbl/day).
In 2006, refining throughputs on own account in Italy and outside Italy were 38.04 mmtonnes, down 0.75 mmtonnes from 2005, or 1.9% due mainly to lower throughputs at third parties refineries. Refining throughputs at own refineries were stable. In particular, refining throughputs increased at the Venice, Gela and Taranto refineries and decreased at the Sannazzaro, and Livorno refineries due to maintenance activity. In April, a new unit for heavy residue gasification started operating at the Sannazzaro refinery. Total throughputs on wholly-owned refineries (27.17 mmtonnes) decreased 0.17 mmtonnes from 2005, down 0.6%; balanced capacity of refineries was fully utilized. Thanks to the continuous upgrading of its manufacturing process, Eni’s refining system can boast a high level of efficiency, flexibility and product quality. At 57%, the conversion index2 of Eni’s refineries compares well with an European average of approximately 33% and enables Eni to extract value from heavy sour grades of the crude feedstock (around 60% of our processed volumes in 2006) which can be purchased with a discount over light/sweet quality crudes like Brent.
High levels of conversion capacity and flexibility enable Eni to:
  • promptly respond to a market characterized by extreme volatility of demand and by rapidly shifting demand-supply imbalances among geographic areas;
  • rigorously respect environmental regulations;
  • steadily improve margins as a result of cost reductions and increasing yields of high-value products.
 

The Sannazzaro refinery (Northern Italy). Pictured is a hydrocracking plant converting the heavy residue of primary distillation into high-value fuels.

     
(1)   It refers to the maximum amount of feedstock that can be processed in certain dedicated facilities of a refinery to obtain finished products.
(2)   It is a ratio of capacity of conversion facilities to primary distillation capacity. The higher the ratio, the higher is the capacity of a refinery to obtain high value products from the heavy residue of primary distillation. Conversion facilities include catalytic crackers, fluid catalytic crackers, hydrocrackers, visbreaking units, and coking units.

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In the medium term, Eni expects certain trends in demand and supply to shape refiners’ investment decisions and strategies, namely the adoption of increasingly strict environmental standards, global imbalances in product availability (especially a deficit of diesel fuel in Europe), a relative abundance of heavy crude and a striving to increase efficiency.
Against this backdrop, Eni plans to boost the profitability of its refining business, capturing market opportunities by means of a focused investment programme, entailing an expenditure of approximately euro 3 billion over the next four years. Main capital projects will be directed to: (i) increase primary and conversion capacity, targeting a complexity index higher than 57%, in view of boosting middle distillate yields, including petrochemical feedstock, and extracting value from equity crude, the availability of which is expected to increase in the Mediterranean basin over the medium term; (ii) improve refinery flexibility in order to optimize processed feedstock and capture market opportunities arising from an expected increasing availability of heavy/sour crude; (iii) achieve high-quality products responsive to expected demand trends and the evolution of product specifications provided for by increasingly tight European standards in term of emissions and environmental preservation; and (iv) enhance operational efficiency of refineries, targeting in particular a higher level of energy efficiency.
  Key projects of refining upgrading

Eni’s plans to revamp its refining system are expected to improve the overall quality of all its assets. In particular, key projects will be implemented at Eni’s largest refineries of Sannazzaro and Taranto.

SANNAZZARO - A medium-term high-grading plan for this asset envisages the construction of a new hydrocracking unit and a new deasphalting unit in order to improve operational flexibility, yields of valuable products, and refinery economics. Expected start-up of these new facilities is by end 2008. Conversion capacity is targeted to increase significantly (from the current 46.2% to a planned 63%), resulting in the production of an additional 1 mmtonnes/y of high-quality middle distillates, mainly diesel fuel and jet-fuel.
This refinery is already one of the most efficient in Europe thanks to its conversion facilities – including a fluid catalytic cracker, an HDCK middle distillate conversion unit and a visbreaking thermal conversion unit, as well as certain desulphurization facilities – enabling the processing of a wide range of crudes from Russia, Africa and Asia, including the Caspian Sea area. This refinery is also integrated with the production of electricity by means of its gasification unit producing syngas to be used as feed gas for the nearby Eni power station at Ferrera Erbognone.

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TARANTO - A medium-term high-grading plan for this asset envisages:
  • construction of a new high pressure hydrocracking unit, targeting production of additional 0.6 mmtonnes/y of high quality diesel oil. Start-up is planned in 2008;
  • construction of a new topping unit, targeting additional process capacity in the range of 4 mmtonnes/y. This plant will be supported by new vacuum and desulphurization facilities to improve yields of middle distillates, and the construction of logistic assets to transport virgin naphtha to Eni’s petrochemical plant in Brindisi, and to market fuels by means of a new storage centre and related pipelines. Eni aims at enlarging consumption areas served by this refinery, covering also the Campania Region as to eliminate supply of refined products to Naples by sea. Start-up is expected in 2009-2010.

With a current conversion rate of 61.1%, Taranto is one of the top performers among Eni’s refineries thanks in particular to the availability of a two-stage thermal conversion plant (visbreaking/thermal cracking) and an RHU conversion plant allowing conversion of high sulphur content residues into valuable fuels and feedstock for Eni’s petrochemical plants. It processes most of the oil produced in Eni’s Val d’Agri fields carried to Taranto through the Monte Alpi pipeline.

Operational efficiency and environmental performance

Eni has always pursued high levels of operational efficiency and environmental performance. Energy consumption of our refineries has shown a steadily decreasing trend for many years to date. In particular, in the 2003-2006 period, we implemented energy saving

  projects enabling us to reduce energy consumption by approximately 90 ktoe/y when fully operational, resulting in a cut in carbon-dioxide emissions in the range of 270 ktonnes/y. Supplies of electricity and steam to Eni’s refineries come from Eni’s power generation plants using highly efficient, combined cycle gas fired technologies, thus further strengthening Group synergies and reducing carbon-dioxide emissions. A strong focus is also dedicated to adopting the best practices and the highest standards of environmental protection and in pursuing an eco-friendly relationship with the territory as witnessed by the large amount of resources allocated to this issue (on average approximately 22% of capital expenditure of the R&M division over the last three years).

Eni can count on a valuable array of logistic assets contributing to the efficiency of its downstream operations.

 

  ENI'S REFINING SYSTEM IN 2006  

Conversion equivalent
(%)

 

Primary balanced refining capacity Eni share
(kbbl/dd)

 

Throughput
(kbbl/dd)

             
Wholly owned refineries  

26.84

 

29.91

 

34.81

Italy            
- Sannazzaro  

46.2

 

170

 

162

- Gela  

143.5

 

100

 

97

- Taranto  

61.1

 

110

 

119

- Livorno  

11.4

 

84

 

80

- Porto Marghera  

22.8

 

70

 

85

             
Partially owned refineries (a)  

50.9

 

177

 

218

             
Total refineries  

57.0

 

711

 

761

     
(a)   Milazzo (Italy), Bayernoil (Germany) and the Ceska Rafinerska (Czech Republic).

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ENI IN 2006 / REFINING & MARKETING

An example of this approach is represented by the Refinars Project at the Sannazzaro Refinery, where the adoption of avant-garde technology for the de-sulfuring of the combustion fumes from the fluid catalytic cracking process has resulted in emission levels well below the standards provided for by applicable regulations.
Eni’s refineries in Italy have production systems fully compliant with standards provided for by the ISO 14001 International Certification; the Taranto, Venice, and Livorno refineries are also compliant with the stricter Environmental Management & Audit Scheme (EMAS) requirements recognized by the European Union.

Logistics

Eni is leader in the activities of storage and transport of petroleum products in Italy. Our logistical integrated infrastructure contributes in a significant way to an efficient management of downstream operations, ensuring a cost-effective product handling from our refineries to our commercial businesses, including marketing, wholesale, aviation and marine. Eni’s logistic operations are supported by 12 directly managed storage sites, a network of pipelines extending over 3,210 kilometers, and a fleet of tanker trucks.
In the medium-term, Eni plans to upgrade its logistic system in line with a planned upgrade of refineries, and to further improve efficiency by implementing an integrated logistic platform according to a “hub” model, designed to centralize handling of product flows, further supporting the efficient integration of refinery and marketing operations.

  Marketing

Eni is leader in the marketing of refined products in Italy and boasts important market shares in selected European areas where it can be supported by Italian production facilities and logistic infrastructure so as to maximize synergies. Popular in the Italian market, the Agip brand is well established in Europe and acknowledged by customers as a guarantee of service and quality.
Eni’s strategy in marketing is focused on extracting full value from its network by means of a selected investment programme and efficiency improvement actions.
In particular, management intends to:
  • broaden the offer of non oil products, increasing the number of service stations with non oil activities from the current 55% to 80% by 2010;
  • enhance brand loyalty by means of promotional initiatives tailored to different customer segments; and
  • grow Eni’s presence in selected European markets where it can leverage on strong brand awareness and logistic advantages.

Over the medium term, Eni plans to grow sales both in Italy and in the rest of Europe, targeting a combined volume of 17.4 billion liters by 2010 from 15.8 in 2006, corresponding to an average annual growth rate of 2.4%, and to match European best practice in terms of efficiency and service level.

ITALY In 2006, retail volumes of refined products marketed on the Agip branded network (8.66 mmtonnes) were down 1% from 2005, with a market share of 29.3%; average throughput in terms of gasoline and diesel fuel was 2,463 kliters, down 1.8% from 2005.
Eni completed the restructuring of its network by divesting the non-core portion of its assets in 2005.
Eni’s network currently consists of 4,356 outlets with high levels of service and efficiency. Eni will continue investing on the upgrading of the network, targeting new opportunities arising from the shifting in customers’ behavior when refuelling the car. In fact, Eni plans to enhance its competitive position and improve its margins in retail operations by developing new service station formats according to European quality and service standards, increasing premium products offer, launching customer-focused marketing initiatives, also providing them an increasingly wide range of services and products beyond fuel, and differentiating fuel quality.

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ENI IN 2006 / REFINING & MARKETING

You&Agip
In March 2007, Eni launched its You&Agip promotional campaign designed to boost customer loyalty to the Agip brand. It is an innovative formula intended to outperform traditional loyalty programmes for motorists, mainly by cancelling the usual time limits, as it is set to last for the next three years until December 31, 2009. Furthermore, the list of prizes will be kept constantly updated thanks to the high number of partners joining the initiative. The defining features of the You&Agip programme include giving customers the freedom how to accumulate points, when to spend them and what kind of reward to choose. Points can be accumulated not only by buying fuel, but also by buying all the other services and products sold at AgipCafè outlets.
 

 

REST OF EUROPE In recent years, Eni’s strategy has focused on selectively growing its market share by means of the acquisition of assets in European areas with interesting profitability perspectives, mainly in Central-Eastern Europe (in particular Southern Germany, Austria, the Czech Republic and Hungary) in South-Eastern France and the Iberian Peninsula. In pursuing such growth, Eni has been able to reap synergies leveraging on the proximity of target areas to Eni’s production and logistic facilities. Over the last five years, retail volumes of refined products marketed in the rest of Europe have grown more than 50% (equal to a compound average growth rate of 9%).
In 2006, retail sales were 3.82 mmtonnes, up 150 ktonnes from 2005, or 4.1%, particularly in Germany, Spain and Austria due to the ramp-up of new stations purchased or built with higher throughput than the average level of Eni’s network, while a few less efficient outlets were divested.
Currently, Eni’s network in Europe consists of approximately 1,938 outlets with continental standards of service and quality. The main countries where Eni is present are: South-Central Germany with a 4.4% market share, Spain with 3.2%, Austria with 7.2%, Switzerland with 5.8% and South-Western France with 1.2% on national base. In the medium term, Eni will continue to deploy its strategy of selectively growing its market share.
  Wholesale

Eni sells gasolines and fuels: diesel fuel for automotiveuse and for heating purposes, for agricultural vehicles and for vessels, gasolines and fuel oil. Major customers are wholesalers, the agricultural and manufacturing industries, public utilities and transports.
In 2006 Eni’s wholesale sales in Italy were 10.06 mmtonnes, down 0.42 mmtonnes from 2005, or 4%, reflecting mainly a decline in domestic consumption related to mild weather conditions in the fourth quarter of the year, with higher temperatures than the seasonal average.
Sales on wholesale markets outside Italy (4.60 mmtonnes) increased 100 ktonnes, or 2.2%, mainly due to higher sales of diesel fuel in Germany and Spain.

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ENI IN 2006 / REFINING & MARKETING

MULTIENERGY
Eni’s constant attention to the environment has led to the construction of MultiEnergy stations that are equipped with solar panels able to provide all the energy necessary for the functioning of the service station, also providing environmentally-friendly fuels.
The inauguration of the Agip MultiEnergy service station at the Infraserv Höchst industrial park in Germany marks the conclusion of the first phase of the “Zero Regio” project, supported by the European Commission, for the realization of an innovative “multifuel” station supplying zero emission vehicles fuelled by hydrogen.

 

  AGIP BRANDED NETWORK  

2004

 

2005

 

2006

             
Retail sales (mmtonnes)  

12.35

 

12.42

 

12.48

Italy  

8.88

 

8.75

 

8.66

Rest of Europe  

3.47

 

3.67

 

3.82

Average throughput (kliters/no. service station)  

2,488

 

2,479

 

2,470

Italy  

2,527

 

2,509

 

2,463

Rest of Europe  

2,393

 

2,427

 

2,486

Numbers of service stations at year end  

6,225

 

6,282

 

6,294

Italy  

4,329

 

4,349

 

4,356

Rest of Europe  

1,896

 

1,933

 

1,938

 

Other businesses

Eni is a leader in the manufacture, distribution and sale of LPG, lubricants and lubricant bases in Italy, leveraging on its high technology production plants and on its high-quality products.

LPG - In 2006 Eni sold 589 ktonnes of LPG in Italy for heating and automotive use (under the Agip brand and wholesale), with an 18% market share.
Additional 350 ktonnes of LPG were sold through other channels mainly to oil companies and traders.
  LUBRICANTS - Eni operates 8 (owned and co-owned) blending plants, in Italy, Europe, North and South America, Africa and the Far East producing a range of over 650 different blends.
Eni masters international state-of-the-art know-how for the formulation of products for vehicles (engine oil, special fluids and transmission oils) and industries (lubricants for hydraulic systems, industrial machinery and metal processing).
In 2006, retail and wholesale sales in Italy amounted to 133 ktonnes with a 23.9% market share.

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The semi-submersible platform Scarabeo 7 continued operations on the Erha field in Nigeria on behalf of ExxonMobil, as a part of a three-year contract.

 

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

5,696

 

5,733

 

6,979

Operating profit      

203

 

307

 

505

Adjusted operating profit      

215

 

314

 

508

Adjusted net profit      

252

 

328

 

400

Capital expenditure      

186

 

349

 

591

ROACE adjusted   (%)  

10.5

 

12.0

 

12.8

Orders acquired:   (million euro)  

5,784

 

8,395

 

11,172

- Offshore construction       2,867   3,096   3,681
- Onshore construction       2,535   4,720   4,923
- Offshore drilling       107   367   2,230
- Onshore drilling       275   212   338
Order backlog:      

8,521

 

10,122

 

13,191

- Offshore construction       3,420   3,721   4,283
- Onshore construction       4,488   5,721   6,285
- Offshore drilling       317   382   2,247
- Onshore drilling       296   298   376
Employees at year end  

(unit)

 

25,819

 

28,684

 

30,902

       
 
 
     
(a)   Before elimination of intersegment sales.

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ENI IN 2006 / ENGINEERING & CONSTRUCTION

STRATEGIES

Eni operates in engineering, oilfield services and construction both offshore and onshore through Saipem, a company listed on the Italian Stock Exchange (Eni’s interest is 43%). Saipem boasts a strong competitive position in the relevant markets thanks to technological and operational skills, engineering and project management capabilities and ability to operate in complex environments, owing also to the integration with Snamprogetti. Leveraging on these strengths and rising demand for drilling equipment and oilfield services, Saipem intends to carry out the following fundamental strategies:

In order to carry out these strategies, Saipem expects to invest approximately euro 3.5 billion to further expand the geographical reach and operational features of its world-class fleet over the next four years.

 

2006 HIGHLIGHTS

Adjusted net profit was euro 400 million, up euro 72 million from a year ago or 22%, reflecting a better operating performance against the backdrop of favorable trends in the demand for oilfield services.

Return on average capital employed calculated on an adjusted basis was 12.8% in 2006, up 12% from 2005.

Orders acquired amounted to euro 11,172 million, up euro 2,777 million from 2005 (+33.1%), in particular in onshore activities.

Order backlog was euro 13,191 million at December 31, 2006 (euro 10,122 million at December 31, 2005).

 

In the second half of the year, the semi-submersible pipelayer Saipem 7000 was engaged in the execution of various activities in the North Sea, including decommissioning of certain facilities and installation of pipelines and sub-sea facilities.

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ENI IN 2006 / ENGINEERING & CONSTRUCTION

Business areas

OFFSHORE CONSTRUCTION
Saipem has gained a sound competitive positioning in the market of large, complex projects for the development of offshore hydrocarbon fields leveraging on its technical and operational skills, supported by a world-class fleet, the ability to operate in complex environments, and engineering and project management capabilities acquired on the market over recent years. Saipem intends to enhance its market share by means of strengthening its EPIC oriented business model and its relationships with major oil companies and NOCs. Higher levels of profitability are expected to be achieved through outsourcing certain engineering and building activities to low cost centers. Investments will be focused on constantly upgrading and improving
  technical characteristics and capabilities of Saipem’s world-class fleet, and to build local construction centers.
In 2006, revenues were euro 3,033 million accounting for 43% of total revenues. This business delivered a gross margin of euro 366 million, corresponding to 55% of total gross margin, higher than the euro 296 million result reported in 2005. This increase reflected higher activity in the Caspian region and Nigeria.
Among the major orders acquired in 2006 were:
  • a contract for the conversion of an oil tanker into an FPSO unit with production capacity of 1.8 mmbbl for the development of the offshore Gimboa field in Angola for Sonangol P&P;
  • an EPIC contract for Burullus Gas Co for the construction of underwater systems for the development of eight new wells within the expansion plan of the Scarab/Saffron and Simian fields offshore in the Nile Delta;

The deep-water drilling ship Saipem 10000 continued to carry out drilling operations on behalf of Total Exploration & Production Angola, as a part a two-year contract.

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ENI IN 2006 / ENGINEERING & CONSTRUCTION

  • an EPIC-type project for CNR International Limited for the construction of three wellhead towers, a support platform, and interconnecting pipelines and umbilicals within the development of the offshore Olowi field in Gabon.

ONSHORE CONSTRUCTION
Saipem operates in the construction of plants for hydrocarbon production (separation, stabilization, collection of hydrocarbons, pumping stations, water injection) and treatment (removal and recovery of sulphur dioxide and carbon dioxide, fractioning of gaseous liquids, recovery of condensates) and in the installation of large onshore transport systems (pipelines, compression stations, terminals).
Saipem intends to capture opportunities arising from expected increasing demand from oil majors, by leveraging on its solid competitive position and integration with Snamprogetti engineering capabilities.

In 2006, revenues were euro 3,333 million accounting for 48% of total revenues. Gross margin came in at euro 147 million as compared to euro 73 million in 2005. This increase reflected higher activity levels related essentially to the start-up of certain large projects acquired in 2005.

  Among the major orders acquired in 2006 were:
  • an EPC contract for Saudi Aramco for the construction of four trains for gas and crude separation with a total capacity of 1.2 mmbbl/d and production facilities within the development of the onshore Khursaniyah field in Saudi Arabia;
  • an EPC contract for Shell Petroleum Development Company of Nigeria for the laying of pipelines, flowlines and composite fibre optic and high voltage electrical cables within the development Gbaran project. The contract was won in consortium with Desicon Engineering Ltd;
  • an EPC contract for Canaport LNG for the construction of a regasification terminal, inclusive of auxiliary facilities for gas offloading, pumping, vaporization and transmission, in addition to two storage tanks. The contract was won in consortium with the Canadian company SNC - Lavalin.

OFFSHORE DRILLING
Saipem provides offshore drilling services to oil companies mainly in West Africa, the North Sea and the Mediterranean Sea. It boasts significant market positions in the most complex segments of deep and ultra-deep offshore leveraging on the outstanding technical features of its drilling platforms and vessels, capable of drilling holes at a maximum depth of 9,200 meters. Demand for drilling services is expected to increase in future years reflecting exploratory plans of oil majors, leading to a substantial rise in tariffs due to equipment shortage. In view of this, Saipem is planning to built a new drilling rig capable of reaching a 10,000 meter drilling depth.

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ENI IN 2006 / ENGINEERING & CONSTRUCTION

In 2006, revenues were euro 365 million accounting for 5% of total revenues. Gross margin amounted to euro 119 million as compared to euro 65 million in 2005. This increase was supported by higher tariffs for the Scarabeo 3 and Scarabeo 5 semi-submersible platforms and higher activity levels of the Perro Negro 5 jack-up and Scarabeo 4 semi-submersible platform.

The most significant contracts awarded during the period include:
  • a 16-month long contract for the use of the semi-submersible drilling platform Scarabeo 7 in Nigeria for ExxonMobil;
  • a 49-month long contract for the use of the semi-submersible drilling platform Scarabeo 5 in Norway for Statoil;
  • a 27-month long contract for the use of the semi-submersible drilling platform Scarabeo 3 in Nigeria for Addax Petroleum.

ONSHORE DRILLING
Saipem operates in this area as main contractor for the major international oil companies executing its activity mainly in Saudi Arabia, North Africa and Peru, where it can leverage on its knowledge of markets, long-term relations with customers and integration with other business areas.

In 2006, revenues were euro 248 million accounting for 4% of total revenues. Gross margin amounted to euro 38 million as compared to euro 26 million in 2005, reflecting a higher activity level.
The contracts awarded during the period amounted to euro 338 million.

  Capital expenditure

In 2006, capital expenditure in the Engineering and Construction segment (euro 591 million) concerned: (i) the conversion of the Margaux tanker ship into an FPSO vessel that will operate in Brazil on the Golfinho 1 field; (ii) maintenance and upgrading of equipment; (iii) fabrication and installation of facilities in the offshore phase of the Kashagan project in Kazakhstan.
Over the next four-year period, Saipem plans to invest approximately euro 3.5 billion directed to further upgrade its world-class fleet and to build local construction centers in order to strengthen relationship with key host countries, including Kazakhstan, Angola and Nigeria. New vessels which are planned to start operation in the next four years include a drilling rig as outlined above and a pipelayer designed to perform tasks in extreme environments.

 

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ENI IN 2006 / GROUP RESULTS FOR THE YEAR

Group results for the year

Trading environment
Eni’s results from operations and the year to year comparability of its financial results are affected by a number of external factors which exist in the industry environment, including changes in oil, natural gas and refined products prices, industry-wide movements in refining and petrochemical margins and fluctuations in exchange rates and interest rates. Changes in weather conditions from year to year can influence demand for natural gas and some petroleum products for heating, thus affecting results of operations of the natural gas business and, to a lesser extent, of the refining and marketing business.

The trading environment was broadly favorable in 2006 with Brent crude oil prices close to $60/bl, up 19.8% compared to 2005. Natural gas margins increased in 2006 compared to 2005, reflecting
  a favorable trading environment and a softer impact of sector specific regulation in Italy. These positives were partially offset by declining refining margins, which were down by 34.4% compared to 2005.
The euro appreciated by 1% over the dollar.
Petrochemical product margins decreased in 2006 as compared to 2005, essentially due to higher purchase costs of oil-based feedstocks not being completely transferred to selling prices.

 

TRADING ENVIRONMENT INDICATORS  

2004

 

2005

 

2006

Average price of Brent dated crude oil (a)      

38.22

  54.38  

65.14

Average EUR/USD exchange rate (b)      

1.244

  1.244  

1.256

Average price in euro of Brent dated crude oil      

30.72

  43.71  

51.86

Average European refining margin (c)      

4.35

  5.78  

3.79

Average European refining margin in euro      

3.50

  4.65  

3.02

Euribor - three-month euro rate  

(%)

 

2.1

  2.2  

3.1

Libor - three-month dollar rate  

(%)

 

1.6

  3.5  

5.2

     
(a)   In US per barrel. Source: Platt’s Oilgram.
(b)   Source: BCE.
(c)   In US per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations based on Platt’s Oilgram data.

 

RESULTS FOR THE YEAR

2004

      (million euro)  

2005

   

2006

   

Change

   

% Ch.

7,059

    Eni's net profit    

8,788

   

9,217

   

429

   

4.9

(281

)   Exclusion of inventory holding (gains) losses    

(759

)  

33

   

792

     

(133

)   Exclusion of special items:    

1,222

   

1,162

   

(60

)    

5

    - non recurring items    

290

   

239

   

(51

)    

(138

)   - other special items    

932

   

923

   

(9

)    

6,645

    Eni's adjusted net profit    

9,251

   

10,412

   

1,161

   

12.5

 

In 2006 Eni delivered record net profit, up 4.9% from 2005 to euro 9,217 million; on an adjusted base net profit was up 12.5% to euro 10,412 million (which excludes an inventory holding loss of euro 33 million and special charges of euro 1,162 million).
This increase was driven by continued improvements in performance and consistent execution of Eni’s strategy, in a broadly favorable trading environment.
  Special charges for the year were principally related to asset impairments, impacting mainly assets in the Exploration & Production division, environmental provisions, redundancy incentives, risk provisions with respect to certain fines imposed by certain regulatory and antitrust authorities and a deferred tax charge, reflecting the windfall tax levied by the Algerian Government and the supplemental tax rate in the UK.

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ENI IN 2006 / GROUP RESULTS FOR THE YEAR

Total Shareholder Return for the year came in at 14.8%, one of the highest in the industry.

Return on average capital employed (ROACE) calculated on an adjusted basis for the twelve-month
  period ending December 31, 2006 was 22.7% (20.5% in 2005).

The break-down of adjusted net profit by division is shown in the table below:

 

ADJUSTED NET PROFIT BY DIVISION
2004         (million euro)   2005     2006     Change     % Ch.  
4,033     Exploration & Production       6,186     7,279     1,093     17.7  
2,290     Gas & Power       2,552     2,862     310     12.1  
674     Refining & Marketing       945     629     (316 )   (33.4 )
242     Petrochemical       227     174     (53 )   (23.3 )
252     Engineering & Construction       328     400     72     22.0  
(241 )   Other activities       (297 )   (301 )   (4 )   (1.3 )
(86 )   Corporate and financial companies       (142 )   54     196     ..  
(37 )   Unrealized profit in inventory (a)       (89 )   (79 )   10     11.2  
7,127     Adjusted net profit       9,710     11,018     1,308     13.5  
      of which:                            
482     minority interest       459     606     147     32.0  
6,645     Eni’s adjusted net profit       9,251     10,412     1,161     12.5  
     
(a)   Unrealized profit in inventory concerned intragroup sales of goods and services recorded in the assets of the purchasing division as of end of the period.
From January 1, 2006 Eni’s subsidiaries operating in diversified sectors (such as real estate services, insurance and financing intermediation, R&D and training services) are reported in the “Corporate and financing companies” aggregate with exception of Tecnomare which is reported in the Exploration & Production division (previously all these diversified activities were reported in the “Other activities” aggregate). The “Other activities” aggregate includes only Syndial SpA, a subsidiary which runs minor petrochemical activities and reclamation and decommissioning activities pertaining to certain businesses which Eni exited in past years. In order to allow for comparison, 2005 data has been reclassified accordingly; 2004 data has not been reclassified.

 

The Group adjusted net profit for the year was supported by the increase reported in the:
  • Exploration & Production division (up euro 1,093 million, or 17.7%), reflecting a better operating performance (up euro 2.860 million) as a result of higher realizations in dollars (oil up 22.4% and natural gas up 17.8%) combined with increased production volumes sold (up 10.2 mmboe). These positives were offset in part by higher operating costs and amortization charges, and increased exploration expenses. Adjusted net profit for the year was also negatively affected by the effects of exchange rates and a higher tax rate (from 51.8 to 53.9%);
  • Gas & Power division (up euro 310 million, or 12.1%), reflecting a better operating performance (up euro 351 million) resulting from higher natural gas selling margins due to a favorable trading environment and the reduced impact of the tariff regime implemented by the Authority for Electricity and Gas with Resolution No. 248/2004. Growth in natural gas sales by consolidated subsidiaries (up 3.14 bcm, or 3.8%) and in volumes transported out-side Italy contributed positively. On a negative note, transportation activities in Italy posted lower operating results due to the tariff regime enacted by the Authority for Electricity and Gas with Resolution No. 166/2005 and distribution activities suffered from lower volumes. Adjusted net profit for the year was supported by a better performance of certain equity accounted entities;
 
  • Engineering & Construction division (up euro 72 million or 22%), reflecting a better operating performance against the backdrop of favorable trends in the demand for oilfield services.

These increases were partly offset by lower adjusted net profit reported in the Refining & Marketing division (down euro 316 million, or 33.4%), due to a poor operating performance (down euro 424 million) dragged down by a weak refining environment, the appreciation of the euro over the dollar and the impact of a higher level of planned maintenance activity at refineries. Divisional results were also adversely impacted by the weaker performance of marketing activities in Italy due to lower sales as a consequence of the mild weather conditions of the fourth quarter.

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ENI IN 2006 / GROUP RESULTS FOR THE YEAR

CAPITAL EXPENDITURE
2006 capital expenditure amounted to euro 7,833 million, of which 89.7% related to the Exploration & Production, Gas & Power and Refining & Marketing divisions.
Capital expenditure was primarily related to: (i) the development of oil and gas reserves (euro 3,629 million) in particular in Kazakhstan, Angola, Egypt and Italy and exploration projects (euro 1,348 million) particularly in Angola, Egypt, Norway, Nigeria, the Gulf of Mexico and Italy, including also the acquisition of 152,000 square kilometers of new acreage (99% operated by Eni); (ii) the upgrading and maintenance of Eni’s natural gas transport and distribution networks in Italy (euro 785 million); (iii) ongoing construction of combined cycle power plants (euro 5,229 million); (iv) projects aimed at improving flexibility and yields of refineries (euro 376 million), including the start-up of construction of a new hydrocracking unit at the Sannazzaro refinery,
 

and the upgrading of the refined product distribution network in Italy and in the rest of Europe (euro 223 million); and (v) the construction of a new FPSO unit and upgrading of the fleet and logistic centers in the Engineering & Construction division (euro 591 million).

 

CAPITAL EXPENDITURE BY DIVISION:

2004

        (million euro)  

2005

   

2006

   

Change

   

% Ch.

 

4,853

    Exploration & Production      

4,965

   

5,203

   

238

   

4.8

 

1,451

    Gas & Power      

1,152

   

1,174

   

22

   

1.9

 

693

    Refining & Marketing      

656

   

645

   

(11

)  

(1.7

)

148

    Petrochemical      

112

   

99

   

(13

)  

(11.6

)

186

    Engineering & Construction      

349

   

591

   

242

   

69.3

 

49

    Other activities      

48

   

72

   

24

   

50.0

 

119

    Corporate and financial companies      

132

   

88

   

(44

)  

(33.3

)
      Unrealized profit in inventory            

(39

)  

(39

)  

..

 

7,499

           

7,414

   

7,833

   

419

   

5.7

 

 

NET CASH PROVIDED BY OPERATING ACTIVITIES
Net cash provided by operating activities came in at euro 17,001 million. These cash flow enabled us to finance: (i) capital expenditure and investments for euro 7,928 million; (ii) dividend payments amounting to euro 4,832 million; (iii) the repurchase of own shares for euro 1,241 million. Cash from divestments (euro 329 million) and currency translation effects (approximately euro 650 million) also contributed to the reduction in net borrowings.

NET BORROWINGS
Net borrowings at December 31, 2006 were euro 6,767 million, representing a decrease of euro 3,708 million from December 31, 2005 due mainly to cash inflow generated by operating activities (euro 17,001 million). Currency translation effects also contributed to the reduction in net borrowings. Debts and bonds
 

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ENI IN 2006 / GROUP RESULTS FOR THE YEAR

amounted to euro 11,699 million, of which euro 4,324 million were short-term (including the portion of long-term debt due within twelve months for euro 890 million) and euro 7,375 million were long-term.

At December 31, 2006, leverage was 0.16, compared to 0.27 at December 31, 2005.

DIVIDENDS AND SHARE REPURCHASES
In 2006 total cash dividends to Eni shareholders amounted to euro 4,610 million (euro 5,070 million in 2005) of which euro 2,400 million pertained to the payment of the balance of the dividend for fiscal year 2005 and euro 2,210 million pertained to the payment of an interim dividend (euro 0.60 per share) for fiscal year 2006 paid in October 2006.
On May 23-24, 2007, Annual General Meeting is convened to approve a unit dividend of euro 1.25 per share for fiscal year 2006 as proposed by Eni’s Board of Directors. This dividend proposal represents an increase of 13.6% compared to the unit dividend paid for fiscal year 2005 (euro 1.10 per share). If the proposal is approved by shareholders, in June Eni will pay a balance of euro 0.65 per share for fiscal year 2006.
  From January 1 to December 31, 2006 a total of 53.13 million own shares were purchased at a cost of euro 1,241 million (on average euro 23.35 per share). From the beginning of the share buy-back plan (September 1, 2000), Eni has purchase 335 million of its own shares, equal to 8.36% of outstanding capital stock, at a total cost of euro 5,512 million (representing an average cost of euro 16.45 per share).

In future, management plans to distribute significant amounts of cash to shareholders through an attractive and sustainable flow of dividends. Management also plans to continue paying dividends on an interim basis. Cash in excess (i.e. cash available after funding growth, paying dividend and maintaining a stable financial structure) will be returned to shareholders via continuing repurchase of own shares.

 

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ENI IN 2006 / COMMITMENT TO SUSTAINABLE DEVELOPMENT

Commitment to sustainable development

SUSTAINABLE DEVELOPMENT: PERFORMANCE DATA  

2004

 

2005

  2006
                 
Employees in Italy at year-end   (units)  

41,331

 

40,192

 

39,765

of which women      

6,792

 

6,977

 

7,124

Employees outside Italy at year-end   (units)  

30,186

 

32,066

 

33,807

of which women      

3,347

 

3,578

 

3,660

Employees in research and development activities (at year-end)   (units)  

1,470

 

1,420

 

1,160

Injury frequency rate (accidents per million hours worked)   (number)  

4.47

 

3.17

 

3.07

Injury severity rate (day of absence per thousand hours worked)   (number)  

0.11

 

0.10

 

0.09

Number of oil spills   (number)  

226

 

335

 

139

Volumes of oil spilt   (barrels)  

7,814

 

6,908

 

6,151

GHG emissions   (MtCO2eq)  

58.41

 

61.74

 

59.34

Applications for patents   (number)  

60

 

26

 

39

Research and development costs   (million euro)  

257

 

204

 

222

Cost incurred for safety   (million euro)  

292

 

391

 

394

Environmental expenditure   (million euro)  

802

 

1,080

 

1,165

 

A strong commitment to sustainable development, involving each aspect of the business ranging from empowering people, to caring for the environment, developing communities, and technological innovation, has always stood at the heart of Eni’s strategies. In 2006, this commitment was confirmed and empowered. Eni is engaged in improving the sustainability of its business model over the time by means of strengthening the relationship with its stakeholders, improving social performance and increasing the value of intangible assets. Sustainability objectives are expected to become an integral part of its management, planning and development   processes. In light of this, for the first time in its history, Eni addressed in its industrial planning the key challenges and commitments it is expected to cope with in future years, as described in the table below.
2006 marks the first year in which Eni has published a Sustainability Report to communicate more effectively with stakeholders. We now have a more coherent approach to sustainability, and are even more committed to managing and developing our company in a responsible and accountable way.
More detailed information on Eni’s commitment to sustainability is given on Eni’s website in the section Sustainability and in the Report on Sustainability.

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Sustainability issues Challenge Eni’s commitment
Corporate
governance
Increasing focus on transparency and sustainability of corporate governance models and processes
  • strengthen a governance system aligned to international best practices, capable of managing the complexity of the contexts in the several countries in which the Group operates and the challenges of sustainable development;
  • systematically involve stakeholder through suitable ways of engagement.
People Increasing competition to hire and retain qualified personnel and need to empower local resources, at the same time protecting their health and ensuring high standard of workplace safety
  • attract the best domestic and international resources;
  • manage human resources internationally with homogenous tools, promoting diversity;
  • promote health and safety of employees, contractors and local communities;
  • enhance the potential and professional capability of its human resources.
Environmental responsibility Satisfying growing energy needs, while at the same time reducing emissions and the impact on ecosystems
  • develop preferentially fossil sources with low carbon intensity, particularly gas;
  • participate actively in emission trading systems and implement projects aimed at reducing emissions based on the flexible mechanisms suggested by the Kyoto Protocol;
  • mitigate the local environmental impact of its activities by improving environmental performance and recovering and reusing resources;
  • reduce its ecological footprint also by means of remediation and reclaiming activities;
  • preserve biodiversity also by means of improved monitoring techniques of onshore and offshore ecosystems.
Innovation Strategic role of innovation in ensuring a sustainable use of energy sources
  • develop technologies aiming at increasing availability of hydrocarbons, maximizing recoverability of existing reserves and protecting safety and the environment in the exploration of new resources;
  • reduce its impact on climate change by investing in innovation capable of generating discontinuity such as emerging solar technologies;
  • manufacture fuels that anticipate future regulation requirements, evolution of engines and of market demands, also by means of pursuing and developing the use of biofuels with high performance and low environmental impact.
Territory and communities Expectations for local community involvement and support
  • promote stakeholder engagement also on industrial projects aimed at enhancing the value of socio-economic systems of the countries and local communities where Eni operates;
  • cooperate with governments and local authorities and with international non-governmental organizations on crucial issues;
  • promote actions for supporting the ability for autonomous development of local communities.

 

Human resources and organization

In Eni’s view, all men and women working within its global organization represent an asset to be safeguarded and enhanced with the utmost care, in the conviction that a highly-motivated, talented and well trained workforce is key to the creation of sustainable value in the long term. Eni’s main objectives for its human resources are:
  • to guarantee safety and health of all employees and contractors;
  • to implement initiatives for the management and development of human resources, ensuring personnel development and growth are consistentwith the evolution of the business;
 
  • to attract and retain the best resources at domestic and international level through strong links with universities and research centers and actively contributing to the training of young generations;
  • to develop and share know-how through the systematization and dissemination of knowledge and the best international corporate practices;
  • to manage human resources internationally with homogenous tools, respecting local regulations and cultures;
  • to obtain excellent results in industrial relations at domestic and international level.

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MANAGEMENT AND DEVELOPMENT OF HUMAN RESOURCES
Eni implemented various initiatives aimed at improving evaluation and development of human resources. In particular, Eni completed a plan of management rejuvenation and enhanced the tools for evaluation of development potential of resources, coupling the appraisals made at (hierarchical and functional) line level with those performed by external experts. These activities were addressed to key managers, developing young managers and newly recruited graduates. Eni performed an updating of policies directed to employees outside Italy and introduced compensation schemes adequate with the dynamics of international resource markets.
With nearly 46% of its employees of non-Italian nationality, Eni has always considered diversity as an element generating value and the ability in managing it as a key factor for success. In the countries where it operates, Eni promotes the development of skills of local human resources and the construction of a shared culture by means of training initiatives addressing issues of intercultural diversity.

TRAINING
Eni considers training one of the strong points of the management of human resources.
The number of hours dedicated to training and the number of employees participating in training initiatives are evidence of Eni’s significant commitment in Italy and outside Italy.
In 2006, expenditure for training amounted to euro 57.2 million. In particular in Italy, a total of 1,167,633 training hours were provided to a total of 23,941 employees

  (232 senior managers, 6,822 middle managers and senior staff, 12,180 employees and 6,192 workers) for a total of 90,319 participations.

INDUSTRIAL RELATIONS
Industrial relations within a consolidated and structured system represented an efficient and consistent support to Eni’s strategic choices and to the completion of reorganization processes underway. Internationally,
Eni continued its dialogue with workers’ unions in specific forums such as the European Works Council. Eni’s Multicultural Training Project, which takes place every year in a different country with the cooperation of members of the EWC, held training courses in France addressed to 300 employees of Saipem SA. This course was awarded the first prize Etica&Impresa at the end of 2006.

HEALTH
Activities for the protection of health aim at improving general work conditions and are developed according to three main principles:
  • protection of employees’ health;
  • prevention of accidents and professional diseases;
  • promotion of healthier behaviors and life styles in workplaces.

Eni has a network of 307 own health care centers located in its main operating areas of these 217 are located outside Italy. A set of international agreements with the best local and international health centers guarantees efficient service and timely reactions to emergencies.
In particular, outside Italy Eni promotes specific information campaigns for the protection of its employees, their families and local communities, such as those for the prevention of malaria (in Nigeria) and the prevention of HIV transmission (in Nigeria and Congo).

SAFETY
Eni has always been deeply engaged in the issue of the safety of its workers, of the people living in the areas where its industrial sites are located and of its producing assets. Its strategy has been based on:

  • the dissemination of a safety culture within its organization;
  • a common policy, specific guidelines for proper management systems meeting international standards;
  • control, prevention and protection from exposure to dangerous situations;
  • minimization of exposure to risk in all production activities.

 

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In 2006, safety indicators have continued to improve, confirming a trend in place for many years to date. Both the injury frequency and severity rates hit historical lows: the former is calculated as ratio of injuries per million hours worked and was 3.07, down 3% from 2005; the latter is calculated as ratio of lost working days per thousand hours worked and was 0.09, down 10% from 2005. In 2006, Eni spent approximately euro 390 million mainly in facilities to improve safety levels, safety current measures, research and development and training.

Responsibility towards the environment

OUTLOOK
The current focus on global environmental issues spurred by an increasingly tight regulatory framework and socio-political debate stimulates companies to devote a strong commitment to both local and worldwide environmental matters beyond the simple compliance with applicable rules and regulations.
In addition, the current operating context is characterized by increasing risk aversion, due to the progressive internalization of environmental externalities and also the growing participation of local stakeholders in decision making processes. Companies are therefore required to be more transparent on their environmental performance, as they are subject to careful scrutiny by stakeholders.
In all its activities, Eni is actively committed to reducing its environmental footprint, decreasing its energy and water consumption, reducing local pollution of air, water and soil as well as waste production and reclaiming discontinued industrial sites. Special attention is paid to the protection
  of biodiversity. To this end, in 2006 Eni spent approximately euro 1.2 billion to preserve the environment and to support reclamation and remediation activities.

RATIONAL USE OF NATURAL RESOURCES
We manage natural resources aiming at their rational and sustainable use and conservation throughout all Eni’s operations.

Coping with risks of climate change
Eni has been devoting a great deal of effort to mitigate risks of climate change by reducing GHG emissions and energy consumption through a global strategy of carbon management aiming at:
  • preferably developing fossil fuels with low carbon intensity, in particular natural gas;
  • pursuing gas-electricity integration exploiting the high efficiency of combined cycles and co-generation;
  • actively participating in the European emission trading scheme, promoting the reduction of emissions at its industrial sites;
  • implementing Clean Development Mechanisms (CDM) and Joint Implementation Project (JIP) foreseen by the Kyoto protocol;
  • progressively reducing gas flaring and gas venting associated to oil production creating the conditions for monetizing such volumes;
  • developing fuel with low environmental impact and technologies for the separation and the geologic confinement of carbon dioxide and efficient production of hydrogen.

Along these guidelines, Eni has been achieving such environmental results as to be featured as a low carbon dioxide emission company.

 

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Water preservation
Eni effectively manages water consumption by means of actions intended to develop recycling opportunities and minimize water discharge aiming in many instances at achieving better performances than those required by applicable laws.
Eni invested to implement integrated production cycles entailing a limited and combined use of water, to build water treatment plants with the most updated technologies and to adopt monitoring systems capable of providing periodic controls of the most significant water parameters. In 2006, water consumption at 3.2 bcm was stable over the previous year.

Soil protection
The protection of soil and ground water is a crucial matter for the preservation of environment. For years, Eni has been carrying out numerous programs for the protection of soils and the reclamation of soils and ground waters. Eni’s business units are provided with an internal organization that takes care of managerial and technical aspects, using highly qualified external professionals to carry out reclaiming activities.
Eni is also active in the area of waste produced by its industrial units with the aim of reducing its generation and improving its final destination by increasing recycling and recovery.

Oil spills
Production, handling and transport of oil products can give rise to spills of variable size. In order to protect the areas where it operates, Eni defined responsibilities and operating modes aimed at reducing the negative impact of oil spills. In 2006, a total of 139 oil spills were registered for a total of 6,150 bbl of oil spilled, confirming a downward trend.

  MANAGING OPERATIONAL RISKS
The broad scope of Eni’s activities involves a wide range of operational risks such as those of explosion, fire or leakage of toxic products, production of non biodegradable waste. All these events could possibly damage or even destroy plants, facilities, equipment and other property, cause injury or even death to persons or cause environmental damage.
Eni adopted the most stringent guidelines for the evaluation and management of health, safety and environmental (HSE) risks, with the objective of protecting Eni’s employees, contractors and clients, the populations involved in its activity, the environment and being in compliance with local and international rules and regulations. Eni’s guidelines prescribe the adoption of international best practices in setting internal principles, standards and solutions. An ongoing process for identifying, evaluating and managing HSE risks is at the hearth of HSE operations in each phase of the business activity and is performed through the adoption of procedures tailored on the peculiarities of each business and industrial site.
HSE risks are effectively managed through an integrated management system designed along the principles set in Eni’s Model of HSE operations. This is a general procedure to be applied in all its operating sites, based on an annual cycle of planning, implementation, control, review of results and definition of new objectives. The model is directed towards the prevention of risks, the systematic monitoring and control of HSE performance in a continuous improvement cycle subject also to audits by internal and independent experts. Any environmental emergency is managed by business units locally with their own organization under preset reaction plans to foreseeable events aimed at limiting damage and at activating adequate responses.
Eni has two emergency rooms (at Milan and Rome) provided with real time monitoring systems for the collection of data on georeferenced maps for all Eni sites and logistics worldwide. Mathematical models are in place to assess dimension, temporal development and other consequences of certain catastrophic events and to enable a real-time planning of first-aid interventions to help mitigate consequences.
In addition to its own emergency teams, Eni entered international agreements in order to maximize its ability to react in all its operating sites.

 

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Community involvement

Eni operates in over 70 countries respecting the human rights of populations, their territory and the environment, contributing to improving the quality of life and the socio-economic development of the communities where it is present. This commitment is the basis of entrepreneurial behaviors based on the respect for ethnic, social or cultural diversity of the various communities with which Eni interacts.
The search for integration with varied social and cultural situations is part of Eni’s tradition. In order to favor a proper integration Eni:
  • cooperates with national and local authorities and with international NGOs;
  • sponsors initiatives that will proceed autonomously in the social, cultural and environmental fabric of the different communities;
  • promotes dialogue with local communities on the industrial options by means of tool of active participation;
  • favors the improvement of the socio-economic system where it operates wherever possible using local goods and services, consistently with its industrial requirements, in order to maximize local content;
  • extends the initiatives for its personnel to their families and to local communities where it operates, in particular as concerns health.

Eni’s main interventions for the protection and development of local communities concern:

  • Italy: activities included in the intent protocol signed with the Basilicata Region for the Val d’Agri for an overall expenditure of approximately euro 160 million in the 1999-2019 period;
  • Karachaganak: infrastructure projects requested by the local authorities for an overall expenditure of approximately euro 9 million, paid by the Consortium;
  • Caspian Sea: infrastructure projects requested by the local authorities for an overall expenditure of approximately euro 309 million, paid by the Consortium;
  • Libya: recruiting, training, health assistance, archaeology, industrial development, as provided for by the masterplan for an overall expenditure of approximately euro 110 million for a period of 8 years.
  Innovation

Our relentless commitment to technological research and innovation underscores a fundamental belief that technology is a key to increasing our competitive advantage over the long term and promoting sustainable growth. All the global challenges in future years require ingenuity and commitment: from the environmental and climate emergencies to the increasingly difficult access to hydrocarbon reserves; from the identification of discontinuities in the production of energy from renewable sources to the optimization of production processes up to the solution of problems existing in countries where Eni has been present for a long time or where it recently entered. We are conducting research aimed primarily at reducing the costs of finding and recovering hydrocarbons, upgrading heavy oils, monetizing stranded gas and protecting the environment. In the next four-year period, we plan to devote a significant amount of resources to research and development activities in the range of euro 1,5 billion in order to support our strategy in innovation.

In 2006, Eni invested euro 222 million in research and development (euro 204 million in 2005). Of these 39% was directed to the Exploration & Production segment, 32% to the Refining & Marketing segment, 22% to the Petrochemical segment and 7% to the Engineering and Construction segment. In particular we moved forward on our breakthrough technologies: EST (Eni Slurry Technology) for the full exploitation of the heavy barrel, TAP (gas transportation at high pressure) and GTL (gas-to-liquids) for gas monetization, and GHG project as described below.

Conversion of heavy crudes and fractions into light products (EST)
Testing of this technology progressed at the Taranto demonstration plant. This proprietary technology is based on a process of catalytic hydroconversion in the slurry phase of non conventional crudes, extra heavy crudes and refining residues enabling it to fully convert asphaltenes (the hard fraction of heavy crudes) into naphtha, kerosene, diesel fuel. In 2007, Eni plans to complete the collection of information for designing and building its first industrial plant.

 

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Gas to liquids project (GTL)
In 2006, with the cooperation of IFP/Axens, Eni completed preparation of a technology handbook for this proprietary technology aiming at conversion of gas to liquids via Fischer-Tropsch synthesis and the basic engineering for a 37 kbbl/d industrial unit.

GHG Project (Green House Gases)
The Green House Gases research program progressed during the course of the year, aiming at verifying the industrial feasibility of the geological sequestration of carbon dioxide in depleted fields and salty aquifers.

  A technical feasibility study of the geological sequestration of carbon dioxide has been completed and in 2007 Eni expects to start testing this project in a field.

Natural gas high pressure transport (TAP)
The TAP project aims to develop an advanced long distance, high capacity, high pressure and high grade solutions for gas transport targeting:
  • transport on distances over 3,000 kilometers;
  • volumes to be transported in the range of 20-30 billion cubic meters/year;
  • pressure equal to or higher than 15 MPa;
  • use of high and very high grade steel.

The TAP technology is expected to allow a decrease in gas consumption of compressor stations.
In 2006, testing progressed on two infrastructures (one integrated in the system of Snam Rete Gas), a technology handbook was released and a hypothetical 3,400 kilometer long gasline in X100 steel in Central Asia was designed.

 

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Financial Information

SUMMARY OF ACCOUNTING POLICIES AND PRACTICES

Eni prepares its consolidated financial statements in accordance with the International Financial Reporting Standards (IFRS) issued by the International Accounting Standards Board (IASB) and adopted by the European Commission.

The consolidated financial statements of Eni include accounts of the parent company Eni SpA and of all Italian and foreign significant subsidiaries in which Eni directly or indirectly holds the majority of voting rights or is otherwise able to exercise control as in the case of “de facto” controlled entities. Control comprises the power to govern the financial and operating policies of the investee so as to obtain rewards from its activities. Insignificant subsidiaries, jointly controlled entities, and other entities in which the group is in a position to exercise a significant influence through participation in the financial and operating policy decisions of the investee are generally accounted for under the equity method of accounting.

Revenues from sales of crude oil, natural gas, petroleum and petrochemical products are recognized when the products are delivered and title passes to the customer. Revenue recognition in the Engineering & Construction division is based on the stage of completion of contracts as measured on the cost-to-cost basis applied to contractual revenues.

Stock-based compensation to employees is recognized in the profit and loss account based on the fair value of grants awarded to the employee; the portion relevant to the year is calculated pro rata over the vesting period of relevant grants.

Eni enters into various derivative financial transactions to manage exposures to certain market risks, including foreign currency exchange rate risks, interest rate risks and commodity risks. From January 1, 2005, such derivative financial instruments are assets and liabilities recognized at fair value starting on the date on which a derivative contract is entered into and are subsequently reassessed at fair value. Derivatives are designated as hedges when the hedging relationship between the hedged item or transaction and the hedging instrument is highly effective and formally documented. Changes in the fair value of hedging derivatives are recognized: (i) for fair value hedges, hedging the exposure to changes in the fair value of a recognized asset or liability, in the profit and loss account; (ii) for cash flow hedges, hedging exposure to variability in cash flows, the effective portion is recognized directly in equity, while the ineffective portion in the profit and loss account; subsequently amounts taken to equity are transferred to the profit and loss account when the hedged transaction occurs. Changes in fair value of derivatives held for trading purposes, i.e. derivatives for which the hedging relationship is not formally documented or is ineffective, are recognized in the profit and loss account. Eni does not enter into derivative transactions on a speculative basis.

Inventories of crude oil, natural gas and oil products are stated at the lower of cost and net realizable value. Cost is determined based on the weighted-average cost method. Contract work in progress is recorded on the basis of contractual considerations by reference to the stage of completion of a contract measured on a cost-to-cost basis.

Property, plant and equipment and intangible assets are stated at cost less accumulated depreciation and accumulated, losses impairment. Depreciation, depletion and amortization of oil and gas properties (capitalized costs incurred to obtain access to proved reserves and to provide facilities for extracting, gathering and storing oil and gas) is calculated based on the Unit-Of-Production (UOP) method on proved reserves or proved developed reserves. Exploratory costs (costs associated with exploratory activities for oil and gas producing properties) are capitalized and fully amortized as incurred. Other tangible assets and intangibles with a defined useful life are amortized systematically, based on the straight-line method. Goodwill and intangibles lacking a defined useful life are not amortized but are reviewed periodically for impairment. Eni assesses its property, plant and equipment and intangible assets, including goodwill, for possible impairment if there are events or changes in circumstances that indicate that the carrying values of the assets are not recoverable.

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Such indicators include changes in the Group’s business plans, changes in commodity prices leading to unprofitable performance and, for oil and gas properties, significant downward revisions of estimated proved reserve quantities.

Asset retirement obligations, that may be incurred for the dismantling and removal of assets and the reclamation of sites, are evaluated estimating the costs to be incurred when the asset is retired. Future estimated costs are discounted when the settlement date is in a long-time horizon in order to reflect the time value of money. Initial estimate is reviewed periodically to reflect changes in circumstances and other factors surrounding the estimate, including the discount rates. The company recognizes material provisions for asset retirement in the upstream business. No significant asset retirement obligations associated with any legal obligations to retire refining, marketing and transportation (downstream) and chemical long-lived assets are generally recognized, as indeterminate settlement dates for the asset retirement prevent estimation of the fair value of the associated asset retirement obligation.

Provisions, including environmental liabilities, are recognized when the group has a present obligation (legal or constructive) as a result of a past event, when is probable that an outflow of resources embodying economic benefit will be required to settle the obligation, and when the obligation can be reliably estimated. The initial estimate to settle the obligation is discounted when the effect of the time value of money is material. The estimate is reviewed periodically to take account of changes in costs expected to be incurred to settle the obligation and other factors, including changes in the discount rates.

Eni is a party to a number of legal proceedings arising in the ordinary course of business. Although Eni’s management does not currently expect a material adverse effect on Eni’s financial position and results of operations on the basis of information available to date and taking account of existing provisions, there can be no assurance that in the future Eni will not incur material charges in connection with pending litigations as new information becomes available and new developments may occur. For further information about pending litigations, see “Legal proceedings”, note 25 to the consolidated financial statements of Eni’s Annual Report 2006.

The preparation of consolidated financial statements requires management to apply accounting methods and policies that are based on difficult or subjective judgments, estimates based on past experience and assumptions determined to be reasonable and realistic based on the related circumstances. The application of these estimates and assumptions, particularly those affecting estimates of proved reserves, asset impairments and contingent liabilities, affects the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the balance sheet date and the reported amounts of income and expenses during the reporting period. Actual results may differ from these estimates given the uncertainty surrounding the assumptions and conditions upon which estimates are based.

For further information regarding accounting policies and practices, see “Evaluation criteria” and “Use of accounting estimates” in the Notes to the consolidated financial statements of Eni’s Annual Report 2006.

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CONSOLIDATED FINANCIAL STATEMENTS

PROFIT AND LOSS ACCOUNT   (million euro)   2004   2005   2006
                   
Profit and loss account                  
Revenues                  
Net sales from operations   57,545     73,728     86,105  
Other income and revenues   1,377     798     783  
Total revenues   58,922     74,526     86,888  
Operating expenses                  
Purchases. services and other   (38,347 )   (48,567 )   (57,490 )
- of which significant non recurring events and operations   5     (290 )   (239 )
Payroll and related costs   (3,245 )   (3,351 )   (3,650 )
Total operating expenses   (41,592 )   (51,918 )   (61,140 )
Depreciation, amortization and impairments   (4,931 )   (5,781 )   (6,421 )
OPERATING PROFIT   12,399     16,827     19,327  
Financial income   2,589     3,131     4,132  
Financial expense   (2,745 )   (3,497 )   (3,971 )
Financial income (expense)   (156 )   (366 )   161  
Effects of investments accounted for using the equity method   332     737     795  
Other income (expense) from investments   488     177     108  
Income (expense) from investments   820     914     903  
PROFIT BEFORE INCOME TAXES   13,063     17,375     20,391  
Income taxes   (5,522 )   (8,128 )   (10,568 )
NET PROFIT   7,541     9,247     9,823  
Pertaining to:                  
- Eni   7,059     8,788     9,217  
- minority interest   482     459     606  

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BALANCE SHEET   (million euro)   Dec. 31, 2004   Dec. 31, 2005   Dec. 31, 2006
                   
ASSETS                  
Current assets                  
Cash and cash equivalents   1,003     1,333     3,985  
Other financial assets for trading or available for sale   1,266     1,368     972  
Trade and other receivables   13,734     17,902     18,799  
Inventories   2,847     3,563     4,752  
Income tax receivables   674     697     658  
Other current assets   588     369     855  
Total current assets   20,112     25,232     30,021  
Non-current assets                  
Property, plant and equipment   40,586     45,013     44,312  
Other tangible assets               629  
Inventories - compulsory stock   1,386     2,194     1,827  
Intangible assets   3,313     3,194     3,753  
Investments accounted for using the equity method   3,156     3,890     3,886  
Other investments   529     421     360  
Other financial assets   936     1,050     805  
Deferred tax assets   1,827     1,861     1,725  
Other non-current assets   1,008     995     994  
Total non-current assets   52,741     58,618     58,291  
TOTAL ASSETS   72,853     83,850     88,312  
LIABILITIES AND SHAREHOLDERS’ EQUITY                  
Current liabilities                  
Short-term financial liabilities   4,150     4,612     3,400  
Current portion of long-term debt   927     733     890  
Trade and other payables   10,533     13,095     15,995  
Taxes payable   2,498     3,430     2,830  
Other current liabilities   505     613     634  
Total current liabilities   18,613     22,483     23,749  
Non-current liabilities                  
Long-term debt   7,607     7,653     7,409  
Provisions for contingencies   5,736     7,679     8,614  
Provisions for employee benefits   982     1,031     1,071  
Deferred tax liabilities   3,948     4,890     5,852  
Other non-current liabilities   427     897     418  
Total non-current liabilities   18,700     22,150     23,364  
TOTAL LIABILITIES   37,313     44,633     47,113  
                   

(million euro)

  Dec. 31, 2004     Dec. 31, 2005     Dec. 31, 2006  
Shareholders’ equity                  
Minority interests   3,166     2,349     2,170  
Shareholders’ equity:                  
Share capital: 4,005,358,876 fully paid shares nominal value euro 1 each (the same amount as of December 31, 2005)   4,004     4,005     4,005  
Share premium                  
Other reserves   9,629     10,910     6,013  
Retained earnings   14,911     17,381     25,168  
Net profit   7,059     8,788     9,217  
Treasury shares   (3,229 )   (4,216 )   (5,374 )
Total Eni Shareholders’ equity   32,374     36,868     39,029  
TOTAL SHAREHOLDERS’ EQUITY   35,540     39,217     41,199  
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY   72,853     83,850     88,312  

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STATEMENTS OF CASH FLOW   (million euro)   2004   2005   2006
                   
Net profit of the year   7,541     9,247     9,823  
Depreciation and amortization   4,598     5,509     6,153  
Revaluations, net   27     (288 )   (386 )
Net change in provisions for contingencies   418     1,279     (86 )
Net change in the provisions for employee benefits   49     18     72  
Gain on disposal of assets, net   (793 )   (220 )   (59 )
Dividend income   (72 )   (33 )   (98 )
Interest income   (198 )   (214 )   (387 )
Interest expense   567     654     346  
Exchange differences   (79 )   (64 )   6  
Income taxes   5,522     8,128     10,568  
Cash generated from operating profit before changes in working capital   17,580     24,016     25,952  
(Increase) decrease:                  
- inventories   (355 )   (1,402 )   (953 )
- trade and other receivables   (1,241 )   (4,413 )   (1,952 )
- other assets   43     351     (315 )
- trade and other payables   727     3,030     2,146  
- other liabilities   (83 )   12     50  
Cash from operations   16,671     21,594     24,928  
Dividends received   394     366     848  
Interest received   167     214     395  
Interest paid   (533 )   (619 )   (294 )
Income taxes paid   (4,199 )   (6,619 )   (8,876 )
NET CASH PROVIDED FROM OPERATING ACTIVITIES   12,500     14,936     17,001  
Investments:                  
- tangible assets   (6,785 )   (6,558 )   (6,138 )
- intangible assets   (714 )   (856 )   (1,695 )
- consolidated subsidiaries and businesses         (73 )   (46 )
- investments   (316 )   (54 )   (42 )
- securities   (675 )   (464 )   (49 )
- financing receivables   (470 )   (683 )   (516 )
- change in payables and receivables in relation to investments and capitalized depreciation   (13 )   149     (26 )
Cash flow from investments   (8,973 )   (8,539 )   (8,512 )
Disposals:                  
- tangible assets   279     99     237  
- intangible assets   13     13     12  
- consolidated subsidiaries and businesses   538     252     8  
- investments   61     178     36  
- securities   659     369     382  
- financing receivables   808     804     794  
- change in payables and receivables in relation to disposals   (1 )   9     (8 )
Cash flow from disposals   2,357     1,724     1,461  
Net cash used in investing activities (*)   (6,616 )   (6,815 )   (7,051 )
Proceeds from long-term debt   1,229     2,755     2,888  
Payments of long-term debt   (797 )   (2,978 )   (2,621 )
Reductions of short-term debt   (4,175 )   (317 )   (949 )
    (3,743 )   (540 )   (682 )
Net capital contributions by/to minority shareholders   1     24     22  
Net repurchase of shares by Eni subsidiaries   (22 )   (30 )   (477 )
Acquisitions of additional interests in consolidated subsidiaries   643     (3 )   (7 )
Sale of additional interests in consolidated subsidiaries               35  
Dividends to shareholders   (3,076 )   (6,288 )   (4,832 )
- of which to Eni shareholders   (2,828 )   (5,070 )   (4,610 )
Net repurchase of Eni shares   (65 )   (987 )   (1,156 )
Net cash used in financing activities   (6,262 )   (7,824 )   (7,097 )
Effect of change in consolidation   12     (38 )   (4 )
Effect of exchange differences   (67 )   71     (197 )
Net cash flow for the period   (433 )   330     2,652  
Cash and cash equivalent at beginning of the year   1,436     1,003     1,333  
Cash and cash equivalent at end of the year   1,003     1,333     3,985  
     
(*)   Net cash used in investing activities includes some investments which Eni, due to their nature (temporary cash investments or carried on in order to optimize management of treasury operations) are considered as a reduction of net borrowings as defined in the "Financial Review" in the "Report of the Directors".

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Contents

ENI IN 2006 / FINANCIAL INFORMATION

NON-GAAP MEASURES

Reconciliation of reported operating profit and net profit to results on an adjusted basis
Management evaluates Group and business performance on the basis of adjusted operating profit and adjusted net profit, which are arrived at by excluding inventory holding gains or losses and special items. Further, finance charges on finance debt, interest income, charges or income deriving from the fair value evaluation of derivative financial instruments held for trading purposes, and exchange rate differences are excluded when determining adjusted net profit of each business segment.

The taxation effect of such items excluded from adjusted net profit is determined based on the specific rate of taxes applicable to each item, with the exception for finance charges or income, to which the Italian statutory tax rate of 33% is applied.

Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or U.S. GAAP. Management includes them to facilitate comparison of base business performance across periods and allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models. In addition, management uses segmental adjusted net profit when calculating return on average capital employed (ROACE) by each business segment.

The following is a description of items which are excluded from the calculation of adjusted results.

Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold calculated using the weighted-average cost method of inventory accounting.

Special items include certain relevant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-recurring items under such circumstances; or (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past periods or are likely to occur in future ones. As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. In addition the effect of the fair value evaluation of derivative financial instruments held for trading purposes and exchange rate differences are excluded from the adjusted net profit of business segments. Therefore, the adjusted net profit of business segments includes finance charge or income deriving from certain segment-operated assets, i.e., interest income on certain receivable financing and securities related to operations and finance charge pertaining to the accretion of certain provisions recorded on a discounted basis (as in the case of the asset retirement obligations in the Exploration & Production division).

Finance charges or interest income and related taxation effects excluded from the adjusted net profit of the business segments are allocated on the aggregate Corporate and financial companies.

For a reconciliation of adjusted operating profit and adjusted net profit to reported operating profit and reported net profit see tables below.

- 66 -


Contents

ENI IN 2006 / FINANCIAL INFORMATION

 

(million euro)

   2006  
   

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

                                                       
Reported operating profit  

15,580

   

3,802

   

319

   

172

   

505

   

(622

)  

(296

)  

(133

)  

19,327

 
Exclusion of inventory holding (gains) losses        

(67

)  

215

   

(60

)                          

88

 
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

55

   

109

   

13

         

62

               

239

 
Other special charges:  

183

   

92

   

147

   

94

   

3

   

261

   

56

         

836

 
     environmental charges        

44

   

111

               

126

   

11

         

292

 
     asset impairments  

231

   

51

   

14

   

50

   

1

   

22

               

369

 
     gains on disposal of assets  

(61

)                                            

(61

)
     provisions to the reserve
     for contingencies
             

8

   

31

         

75

               

114

 
     provision for redundancy
     incentives
 

13

   

37

   

47

   

19

   

2

   

17

   

43

         

178

 
     other        

(40

)  

(33

)  

(6

)        

21

   

2

         

(56

)
Special items of operating profit  

183

   

147

   

256

   

107

   

3

   

323

   

56

         

1,075

 
Adjusted operating profit  

15,763

   

3,882

   

790

   

219

   

508

   

(299

)  

(240

)  

(133

)  

20,490

 
Net financial (expense) income (*)  

(59

)  

16

                     

(7

)  

205

         

155

 
Net income from investments (*)  

85

   

489

   

184

   

2

   

66

   

5

               

831

 
Income taxes (*)  

(8,510

)  

(1,525

)  

(345

)  

(47

)  

(174

)        

89

   

54

   

(10,458

)
Tax rate (%)  

53.9

   

34.8

   

35.4

                                 

48.7

 
Adjusted net profit  

7,279

   

2,862

   

629

   

174

   

400

   

(301

)  

54

   

(79

)  

11,018

 
of which:                                                      
- net profit of minorities                                                  

606

 
- Eni’s adjusted net profit                                                  

10,412

 
                                                       
Eni’s reported net profit                                                  

9,217

 
Exclusion of inventory holding (gains) losses                                                  

33

 
Exclusion of special items                                                  

1,162

 
- Non-recurring (income) charges                                                  

239

 
- Other special charges                                                  

923

 
Eni’s adjusted net profit                                                  

10,412

 
     
(*)   Excludes special items.

- 67 -


Contents

ENI IN 2006 / FINANCIAL INFORMATION

(million euro)

   2005  
   

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

                                                       
Reported operating profit  

12,592

   

3,321

   

1,857

   

202

   

307

   

(934

)  

(377

)  

(141

)  

16,827

 
Exclusion of inventory holding (gains) losses        

(127

)  

(1,064

)  

(19

)                          

(1,210

)
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

290

                                       

290

 
Other special charges:  

311

   

47

   

421

   

78

   

7

   

638

   

149

         

1,651

 
     environmental charges        

31

   

337

               

413

   

54

         

835

 
     asset impairments  

247

   

1

   

5

   

29

   

4

   

75

   

2

         

363

 
     provisions to the reserve
     for contingencies
             

39

   

36

         

126

               

201

 
     increase insurance charges  

57

   

6

   

30

   

17

         

4

   

64

         

178

 
     provision for redundancy
     incentives
 

7

   

8

   

22

   

4

   

3

   

6

   

29

         

79

 
     other        

1

   

(12

)  

(8

)        

14

               

(5

)
Special items of operating profit  

311

   

337

   

421

   

78

   

7

   

638

   

149

         

1,941

 
Adjusted operating profit  

12,903

   

3,531

   

1,214

   

261

   

314

   

(296

)  

(228

)  

(141

)  

17,558

 
Net financial (expense) income (*)  

(80

)  

37

                           

(296

)        

(339

)
Net income from investments (*)  

10

   

370

   

231

   

3

   

141

   

(1

)  

23

         

777

 
Income taxes (*)  

(6,647

)  

(1,386

)  

(500

)  

(37

)  

(127

)        

359

   

52

   

(8,286

)
Tax rate (%)  

51.8

   

35.2

   

34.6

                                 

46.0

 
Adjusted net profit  

6,186

   

2,552

   

945

   

227

   

328

   

(297

)  

(142

)  

(89

)  

9,710

 
of which:                                                      
- net profit of minorities                                                  

459

 
- Eni’s adjusted net profit                                                  

9,251

 
                                                       
Eni’s reported net profit                                                  

8,788

 
Exclusion of inventory holding (gains) losses                                                  

(759

)
Exclusion of special items                                                  

1,222

 
- Non-recurring (income) charges                                                  

290

 
- Other special charges                                                  

932

 
Eni’s adjusted net profit                                                  

9,251

 
     
(*)   Excludes special items.

- 68 -


Contents

ENI IN 2006 / FINANCIAL INFORMATION

(million euro)

   2004  
   

E&P

 

G&P

 

R&M

 

Petrochemicals

 

E&C

 

Other activities

 

Corporate and financial companies

 

Unrealized profit in inventory

 

Group

                                                       
Reported operating profit  

8,185

   

3,428

   

1,080

   

320

   

203

   

(395

)  

(346

)  

(59

)  

12,399

 
Exclusion of inventory holding (gains) losses        

(12

)  

(393

)  

(43

)                          

(448

)
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

5

                                       

5

 
Other special charges:  

17

   

27

   

236

   

(14

)  

12

   

172

   

176

         

626

 
     environmental charges        

5

   

142

               

84

   

72

         

303

 
     asset impairments  

287

   

6

   

21

   

3

         

19

               

336

 
     gains on disposal of assets  

(320

)                                            

(320

)
     provisions to the reserve
     for contingencies
 

29

   

18

   

77

   

3

   

1

   

15

               

143

 
     increase insurance charges                                      

91

         

91

 
     provision for redundancy
     incentives
 

2

   

10

   

20

   

6

   

10

   

6

   

11

         

65

 
     other  

19

   

(12

)  

(24

)  

(26

)  

1

   

48

   

2

         

8

 
Special items of operating profit  

17

   

32

   

236

   

(14

   

12

   

172

   

176

         

631

 
Adjusted operating profit  

8,202

   

3,448

   

923

   

263

   

215

   

(223

)  

(187

)  

(59

)  

12,582

 
Net financial (expense) income (*)  

(85

)  

31

   

5

                     

(107

)        

(156

)
Net income from investments (*)  

9

   

215

   

96

   

2

   

118

   

4

   

(14

)        

430

 
Income taxes (*)  

(4,093

)  

(1,404

)  

(350

)  

(23

)  

(81

)  

(22

)  

222

   

22

   

(5,729

)
Tax rate (%)  

50.4

   

38.0

   

34.2

                                 

44.6

 
Adjusted net profit  

4,033

   

2,290

   

674

   

242

   

252

   

(241

)  

(88

)  

(37

)  

7,127

 
of which:                                                      
- net profit of minorities                                                  

482

 
- Eni’s adjusted net profit                                                  

6,645

 
                                                       
Eni’s reported net profit                                                  

7,059

 
Exclusion of inventory holding (gains) losses                                                  

(281

)
Exclusion of special items                                                  

(133

)
- Non-recurring (income) charges                                                  

5

 
- Other special charges                                                  

(138

)
Eni’s adjusted net profit                                                  

6,645

 
     
(*)   Excludes special items.

- 69 -


Contents

ENI IN 2006 / FINANCIAL INFORMATION

(million euro)

ANALYSIS OF SPECIAL ITEMS
                         
2004         2005     2006     Change  
5     Non-recurring (income) charges   290     239     (51 )
626     Other special charges:   1,651     836     (815 )
303     environmental charges   835     292     (543 )
336     asset impairments   363     369     6  
(320 )   gains on disposal of assets         (61 )   (61 )
234     provisions to the reserve for contingencies   379     114     (265 )
      of which: increase insurance charges   178           (178 )
65     provisions for redundancy incentives   79     178     99  
8     other   (5 )   (56 )   (51 )
631     Special items of operating profit   1,941     1,075     (866 )
      Net financial (expense) income   27     (6 )   (33 )
(390 )   Net income from investments   (137 )   (72 )   65  
      of which:                  
           gain on the disposal of Italiana Petroli (IP)   (132 )         132  
           gain on Galp Energia SGPS SA (disposal assets Rede Electrica National)         (73 )   (73 )
(308 )        gain on the disposal of shares of Snam Rete Gas SpA                  
(374 )   Income taxes   (609 )   165     774  
      of which:                  
           supplemental tax rate UK         91     91  
           windfall tax Algeria         179     179  
           legal proceeding in Venezuela         77     77  
(133 )   Total special items of net profit   1,222     1,162     (60 )

 

- 70 -


Contents

ENI IN 2006 / FREQUENTLY USED TERMS

Frequently Used Terms

For a reconciliation of Summarized Group Balance Sheet and Summarized Group Cash Flow Statement with the corresponding statutory tables see Eni’s 2006 Annual Report, Reconciliation of Summarized Group Balance Sheet and Statement Of Cash Flows to statutory schemes” pages 77-80.

SUMMARIZED GROUP BALANCE SHEET
Summarized Group Balance Sheet aggregates the amount of assets and liabilities derived from the statutory balance sheet in accordance with functional criteria which consider the enterprise conventionally divided into the three fundamental areas focusing on resource investments, operations and financing. Management believes that this summarized group balance sheet is useful information in assisting investors to assess Eni’s capital structure and to analyze its sources of funds and investments in fixed assets and working capital. Management uses the Summarized Group Balance Sheet to calculate key ratios such as return on capital employed (ROACE) and the proportion of net borrowings to shareholders’ equity (leverage) intended to evaluate whether Eni’s financing structure is sound and well-balanced.

 

SUMMARIZED GROUP BALANCE SHEET   (million euro)   Dec. 31, 2004   Dec. 31, 2005   Dec. 31, 2006
                   
Fixed assets                  
Property, plant and equipment, net  

40,586

   

45,013

   

44,312

 
Other tangible assets              

629

 
Inventories - compulsory stock  

1,386

   

2,194

   

1,827

 
Intangible assets, net  

3,313

   

3,194

   

3,753

 
Investments, net  

3,685

   

4,311

   

4,246

 
Accounts receivable financing and securities related to operations  

695

   

775

   

557

 
Net accounts payable in relation to capital expenditure  

(888

)  

(1,196

)  

(1,090

)
   

48,777

   

54,291

   

54,234

 
Net working capital                  
Inventories  

2,847

   

3,563

   

4,752

 
Trade accounts receivable  

10,525

   

14,101

   

15,230

 
Trade accounts payable  

(5,837

)  

(8,170

)  

(10,528

)
Taxes payable and reserve for net deferred income tax liabilities  

(3,056

)  

(4,857

)  

(5,396

)
Reserve for contingencies  

(5,736

)  

(7,679

)  

(8,614

)
Other operating assets and liabilities (a)  

(555

)  

(526

)  

(641

)
   

(1,812

)  

(3,568

)  

(5,197

)
Employee termination indemnities and other benefits  

(982

)  

(1,031

)  

(1,071

)
Capital employed, net  

45,983

   

49,692

   

47,966

 
Shareholders’ equity including minority interests  

35,540

   

39,217

   

41,199

 
Net borrowings  

10,443

   

10,475

   

6,767

 
Total liabilities and shareholders’ equity  

45,983

   

49,692

   

47,966

 
     
(a)   Include operating financing receivables and securities related to operations for euro 249 million (euro 492 million and euro 261 million at December 31, 2005 and September 30, 2006, respectively) and securities covering technical reserves of Padana Assicurazioni SpA for euro 417 million (euro 453 million and euro 550 million at December 31, 2005 and September 30, 2006, respectively).

NET BORROWINGS AND LEVERAGE
Eni evaluates its financial condition by reference to net borrowings, which is the measure of total finance debt less: cash, cash equivalents and certain very liquid investments not related to operations, including among others non-operating financing receivables and securities not related to operations. Non-operating financing receivables consist of amounts due to Eni’s financing subsidiaries from banks and other financing institutions and amounts due to other subsidiaries from banks for investing purposes and deposits in escrow. Securities not related to operations consist primarily of government and corporate securities.

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Leverage is a measure of a company’s level of indebtedness, calculated as the ratio between net borrowings which is calculated by excluding cash and cash equivalents and certain very liquid assets from financial debt, and shareholders’ equity, including minority interests. Management makes use of leverage in order to assess the soundness and efficiency of the Group balance sheet in terms of optimal mix between net borrowings and net equity, and to carry out benchmark analysis with industry standards.
In the medium term, management plans to maintain a strong financial structure targeting a level of leverage up to 0.40.

LEVERAGE (NET BORROWINGS ÷ EQUITY)   (million euro)   Dec. 31, 2004   Dec. 31, 2005   Dec. 31, 2006
                   
Debts and bonds   12,684     12,998     11,699  
Cash and cash equivalents   (1,003 )   (1,333 )   (3,985 )
Securities not related to operations   (793 )   (931 )   (552 )
Non-operating financing receivables   (251 )   (259 )   (395 )
Other items   (194 )            
Net borrowings   10,443     10,475     6,767  
Shareholders’ equity including minority interest   35,540     39,217     41,199  
Leverage   0.29     0.27     0.16  

SUMMARIZED GROUP CASH FLOW STATEMENT AND CHANGE IN NET BORROWINGS
Eni’s Summarized Group Cash Flow Statement derives from the statutory statement of cash flows. It allows to create a link between changes in cash and cash equivalents (deriving from the statutory cash flows statement) occurred from the beginning of period to the end of period and changes in net borrowings (deriving from the summarized cash flow statement) occurred from the beginning of period to the end of period. The measure enabling to make such a link is represented by free cash flow which is the cash in excess of capital expenditure needs. Starting from free cash flow it is possible to determine either: (i) changes in cash and cash equivalents for the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to financing activities), shareholders’ equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange differences; (ii) changes in net borrowings for the period by adding/deducting cash flows relating to shareholders’ equity and the effect of changes in consolidation and of exchange differences.

SUMMARIZED GROUP CASH FLOW STATEMENT   (million euro)   2004   2005   2006
                   
Net profit   7,541     9,247     9,823  
Adjustments to reconcile to cash generated from operating profit before changes in working capital:                  
- amortization and depreciation and other non monetary items   5,092     6,518     5,753  
- net gains on disposal of assets   (793 )   (220 )   (59 )
- dividends, interest, taxes and other changes   5,740     8,471     10,435  
Cash generated from operating profit before changes in working capital   17,580     24,016     25,952  
Changes in working capital related to operations   (909 )   (2,422 )   (1,024 )
Dividends received, taxes paid, interest (paid) received   (4,171 )   (6,658 )   (7,927 )
Net cash provided by operating activities   12,500     14,936     17,001  
Capital expenditure   (7,499 )   (7,414 )   (7,833 )
Investments   (316 )   (127 )   (95 )
Disposals   1,547     542     328  
Other cash flow related to capital expenditure, investments and disposals   97     293     361  

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continued SUMMARIZED GROUP CASH FLOW STATEMENT

(million euro)

  2004     2005     2006  
Free cash flow   6,329     8,230     9,762  
Borrowings (repayment) of debt related to financing activities   211     (109 )   216  
Changes in short and long-term financial debt   (3,743 )   (540 )   (682 )
Dividends paid and changes in minority interests and reserves   (3,175 )   (7,284 )   (6,443 )
Effect of changes in consolidation and exchange differences   (55 )   33     (201 )
NET CASH FLOW FOR THE PERIOD   (433 )   330     2,652  
                   

(million euro)

  2004     2005     2006  
Change in net borrowings                  
Free cash flow   6,329     8,230     9,762  
Net borrowings of acquired companies         (19 )      
Net borrowings of divested companies   190     21     1  
Exchange differences on net borrowings and other changes   (64 )   (980 )   388  
Dividends paid and changes in minority interests and reserves   (3,175 )   (7,284 )   (6,443 )
CHANGE IN NET BORROWINGS   3,280     (32 )   3,708  

ROACE
Return on Average Capital Employed for the Group, on an adjusted basis is the return on Group average capital invested, calculated as the ratio between net adjusted profit before minority interests, plus net finance charges on net borrowings, less the related tax effect and net average capital employed. The tax rate applied on finance charges is the Italian statutory tax rate of 33%. The capital invested as of period-end used for the calculation of net average capital invested is obtained by deducting inventory gains or losses as of in the period, rectified from the related tax effect.
ROACE by business segment is determined as the ratio between adjusted net profit and net average capital invested pertaining to each business segment and rectifying the net capital invested as of period-end, from net inventory gains or losses (after applying the business segment specific tax rate).

ROACE   (million euro)   2004   2005   2006
                   
Adjusted net profit   7,127     9,710     11,018  
Exclusion of after tax finance expenses/interest income   115     42     46  
Adjusted net profit unlevered   7,242     9,752     11,064  
Capital employed, net:                  
- at the beginning of the year   45,240     45,983     49,692  
- at the year end   45,724     48,933     47,999  
Average capital employed, net   45,482     47,458     48,846  
ROACE (%)   15.9     20.5     22.7  

TSR (Total Shareholder Return)
Measures the total return of a share calculated on a yearly basis, based on the change in price from the beginning to the end of year, and dividends distributed and reinvested at the ex-dividend date.

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PRODUCTION SHARING AGREEMENTS (PSA)
In PSAs the national oil company awards the execution of exploration and production activities to the international oil company (contractor). The contractor bears the mineral and financial risk of the initiative and, when successful, recovers capital expenditure and costs incurred in the year (cost oil) by means of a share of production. This production share varies along with international oil prices. In certain PSAs changes in international oil prices affect also the share of production to which the contractor is entitled in order to remunerate its capital invested (profit oil) after costs incurred are repaid by cost oil. A similar scheme applies to buy-back contracts.

POSSIBLE RESERVES
Amounts of hydrocarbons that have a lower degree of certainty than probable reserves and are estimated with lower certainty, for which it is not possible to foresee production.

PROBABLE RESERVES
Amounts of hydrocarbons that are probably, but not certainly, expected to be extracted. They are estimated based on known geological conditions, similar characteristics of rock deposits and the interpretation of geophysical data. Further uncertainty elements may concern: (i) the extension or other features of the field; (ii) economic viability of extraction based on the terms of the development project; (iii) existence and adequacy of transmission infrastructure and/or markets; (iv) the regulatory framework.

PROVED RESERVES
Proved reserves are estimated volumes of crude oil, natural gas and gas condensates, liquids and associated substances which are expected to be retrieved from deposits and used commercially, at the economic and technical conditions applicable at the time of the estimate and according to current legislation. Proved reserves include: (i) proved developed reserves: amounts of hydrocarbons that are expected to be retrieved through existing wells, facilities and operating methods; (ii) non developed proved reserves: amounts of hydrocarbons that are expected to be retrieved following new drilling, facilities and operating methods. On these amounts the company has already defined a clear development expenditure program which is expression of the company’s determination.

RECOVERABLE RESERVES
Amounts of hydrocarbons included in different categories of reserves (proved, probable and possible), without considering their different degree of uncertainty.

RESERVE REPLACEMENT RATIO
Measure of the reserves produced replaced by proved reserves. Indicates the company’s ability to add new reserves through exploration and purchase of property. A rate higher than 100% indicates that more reserves were added than produced in the period. The ratio should be averaged on a three-year period in order to reduce the distortion deriving from the purchase of property or upstream assets, the revision of previous estimates, enhanced recovery, improvement in recovery rates and changes in the value of reserves – in PSAs – due to changes in international oil prices.

RESERVE LIFE INDEX
Ratio between the amount of reserves at the end of the year and total production for the year.


     ABBREVIATIONS
 
bboe


=


billion barrel of oil equivalent
        bbl

=

barrels
     mmcf

=

million cubic feet   kbbl

=

thousand barrels
     bcf

=

billion cubic feet   mmbbl

=

million barrels
     mmcm

=

million cubic meters   bbbl

=

billion barrels
     bcm

=

billion cubic meters   mmtonnes

=

million tonnes
     boe

=

barrel of oil equivalent   ktonnes

=

thousand tonnes
     kboe

=

thousand barrel of oil equivalent   /d

=

per day
     mmboe

=

million barrel of oil equivalent   /y

=

per year
     

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RECONCILIATION OF NET PROFIT AND SHAREHOLDERS’ EQUITY DETERMINED UNDER IFRS TO U.S. GAAP
The following is a summary of the significant adjustments to net profit for 2004, 2005 and 2006 and to shareholders’ equity as of December 31, 2004, 2005 and 2006 that would be required if U.S. GAAP had been applied instead of IFRS in the consolidated financial statements.

(million euro)

  2004     2005     2006  
Net profit pertaining to Eni according to the Financial Statements prepared under IFRS   7,059     8,788     9,217  
Items increasing (decreasing) reported net profit:                  
A. effect of the differences related to companies consolidated under IFRS but carried at equity method under U.S. GAAP   (1 )         (1 )
B. successful-efforts accounting   (82 )   47     359  
C. elimination of assets impairments and revaluations   5           36  
D. deferred income taxes   (21 )   (279 )   (120 )
E. assets associated to the acquisition of a company (portfolio of clients)   (5 )   (5 )   (5 )
F. valuation of inventories   (316 )   (956 )   267  
Gain on disposal of Snamprogetti SpA to Saipem Projects SpA               252  
Effect of the difference between IFRS and U.S. GAAP on investments accounted for using the equity method   34     12     1  
Other adjustments   (280 )   (3 )   (4 )
Effect of U.S. GAAP adjustments on minority interest (a)   8     (21 )   3  
Net adjustment   (658 )   (1,205 )   788  
Net profit in accordance with U.S. GAAP   6,401     7,583     10,005  
Basic profit per share (b)   1.70     2.02     2.71  
Diluted profit per share (b)   1.70     2.01     2.70  
Basic profit per ADS (based on two shares per ADS) (b)   3.39     4.03     5.41  
Diluted profit per ADS (based on two shares per ADS) (b)   3.39     4.03     5.41  
     
(a)   Adjustment to account for minority interest portion of differences A through F, which include 100% of differences between IFRS and U.S. GAAP on less than wholly- owned subsidiaries.
(b)   Amounts in euro.

 

(million euro)

        Dec. 31, 2005     Dec. 31, 2006  
Shareholders’ equity pertaining to Eni according to the Financial Statements prepared under IFRS         36,868     39,029  
Items increasing (decreasing) reported shareholders’ equity: (a)                  
A. effect of the differences related to companies consolidated under IFRS but carried at equity method under U.S. GAAP         37     33  
B. successful-efforts accounting         2,504     2,672  
C. elimination of assets impairments and revaluations         230     311  
D. deferred income taxes         (3,415 )   (3,495 )
E. goodwill         811     786  
E. assets associated with the acquisition of a company (portfolio of clients)         (16 )   (22 )
F. valuation of inventories         (2,036 )   (1,769 )
G. provisions for employees benefits               (32 )
Effect of the difference between IFRS and U.S. GAAP on investments accounted for using the equity method         173     169  
Other adjustments               2  
Effect of U.S. GAAP adjustments on minority interest (b)         (31 )   (28 )
Net adjustment         (1,743 )   (1,373 )
Shareholders’ equity in accordance with U.S. GAAP         35,125     37,656  
     
(a)   Items increasing (decreasing) reported shareholders’ equity of foreign companies are translated into euro at the exchange rate prevailing at the end of each period.
(b)   Adjustment to account for minority interest portion of differences A through G, which include 100% of differences between IFRS and U.S. GAAP on less than wholly-owned subsidiaries.

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Directors and Officers

Eni’s Board of Directors

       

1

 

2

  3   4   5

 

1. Roberto Poli - Chairman
Roberto Poli was appointed Chairman of Eni SpA in May 2002. He is currently President of Poli e Associati SpA, a consulting firm for corporate finance, mergers, acquisitions and reorganizations. From 1966 to 1998
he was Professor of Business Finance at the Università Cattolica of Milan. He is a partner of one of the most important firms for corporate finance and legal affairs.
He is a non executive director in important companies such as Fininvest SpA, Mondadori SpA, Merloni Termosanitari SpA and G.D. SpA. He has been an advisor for extraordinary finance operations for some of the most important companies in Italy. He has also been Chairman of Rizzoli-Corriere della Sera SpA and Publitalia SpA.

2. Paolo Scaroni - Group Chief Executive Officer and General Manager
Paolo Scaroni obtained an economics degree from Milan’s Bocconi University in 1969 and an MBA from Columbia Business School in 1973. For a year following business school, he was an associate at McKinsey & Company. From 1973 until 1985, he held a series of positions with Saint Gobain, culminating with his appointment as President of the Saint Gobain flat glass division. In 1985, Paolo Scaroni became CEO of Techint. During his time at Techint, he was also Vice President of Falck and executive Vice President of SIV, a joint venture between Techint and Pilkington plc.
He joined Pilkington in 1996 and was group CEO until May 2002. From May 2002 to June 2005 he was CEO of Enel, Italy’s leading electricity utility. Paolo Scaroni is a member of the Board of “Il Sole 24 Ore” and of Teatro alla Scala. He is a member of the Supervisory Board of ABN AMRO Bank N.V. (Amsterdam), member of the Board of Overseers of Columbia Business School (New York) and member of the Board of Veolia Environnement (Paris). He was Chairman of Alliance Unichem plc. (UK) from 2005 to July 2006.
  3. Alberto Clô
Alberto Clô is a professor of Industrial Economy at the University of Bologna and was Minister of Industry and Minister of Foreign Trade ad interim in 1995 and 1996. During the Italian presidency of the European Union he was chairman of the Council of Ministers of Industry and Energy of the European Union. In 1996 he was awarded the title of Cavaliere di Gran Croce al Merito of the Republic of Italy. He is a Member of the Board of Directors of ASM Brescia SpA, De Longhi SpA, Italcementi SpA and Società Autostrade SpA.

4. Renzo Costi
Renzo Costi is an attorney and consultant. He served as a magistrate from 1964 to 1968 and is currently professor of commercial company law at the University of Bologna. He was founder, and currently is co-editor, of the magazines “Giurisprudenza Commerciale”, “Banca Impresa e Società” and “Banca, Borsa e titoli di credito”.
He is a member of the Board of Directors of Editrice Il Mulino SpA.

5. Dario Fruscio
Dario Fruscio is a chartered accountant, public auditor and consultant; he is currently Professor of Economics and Management at the University of Pavia and taught at the Accademia Nazionale della Guardia di Finanza of Bergamo. He is Chairman of Italia Turismo SpA.

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6

 

7

  8   9    

 

6. Marco Pinto
Marco Pinto is a magistrate and notary and has previously held various positions as a civil and administrative judge. Since December 2004 he has been professor of the Higher School of Economics and Finance. In 1994 he held the position of Legal Counsel and head of Legislative Department of the Ministry of Foreign Trade and the Ministry of Economics and Finance. From December 2004 to April 2005 he was head of the staff of the Vice President of the Council of Ministers. Since June 2005 he has been Deputy Head of the staff of the Minister of Economics and Finance.

7. Marco Reboa
Marco Reboa is a chartered accountant and auditor.
He is professor of law at the Libero Istituto Universitario Carlo Cattaneo in Castellanza and author of essays on corporate governance, economic evaluation and financial statements. He is the editor of "Rivista dei Dottori Commercialisti" and is a professional advisor in Milan.
He is a member of the Board of Directors of Seat PG SpA, Interpump SpA, IMMSI SpA and Intesa Private Banking SpA. He is Chairman of the Board of Statutory Auditors of Luxottica Group SpA.
  8. Mario Resca
Mario Resca is Chairman of Italia Zuccheri SpA (formerly Eridania SpA), National Board member of U.P.A. (the Italian Advertisers' Association) and Confimprese.
He is non executive Director of Mondadori SpA and special manager of the Cirio Del Monte Group, under special management. In 1974 he was appointed director of Biondi Finanziaria (Fiat Group) and from 1976 to 1991 he was partner of Egon Zehnder. In this period the was appointed director of Lancôme Italia and of companies belonging to the Rizzoli-Corriere della Sera Group and Versace Group. He also served as Chairman of Sambonet SpA, Kenwood Italia SpA and was a founding partner of Eric Salmon & Partners.

9. Pierluigi Scibetta
Pierluigi Scibetta is a chartered accountant and auditor and has been appointed director and auditor of a number of public bodies and companies. In 2003 he was appointed director of the Istituto Superiore per la previdenza e la sicurezza sul lavoro and of the Gestore del Mercato Elettrico SpA. In 2004, he was appointed director of Nucleco SpA. He is a professor of Environmental Economics at the University of Perugia.

 

Board Committees

Internal Control Committee: Marco Reboa - Chairman, Alberto Clô, Renzo Costi, Marco Pinto and Pierluigi Scibetta.

Compensation Committee: Mario Resca - Chairman, Renzo Costi, Marco Pinto and Pierluigi Scibetta.
 

International Oil Committee:
Alberto Clô - Chairman,
Renzo Costi, Dario Fruscio, Marco Reboa and Paolo Scaroni.

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Group Officers

Paolo Scaroni
Chief Executive Officer and General Manager
of the parent company

Marco Mangiagalli
Chief Financial Officer
Stefano Lucchini
Senior Vice President for Public Affairs and Communication
Massimo Mantovani
Senior Vice President for Legal Affairs
Rita Marino
Senior Vice President for Internal Audit
Leonardo Maugeri
Senior Vice President for Strategies and Development
Sergio Polito
Senior Vice President for Procurement
Salvatore Sardo
Senior Vice President for Human Resources & Business Services
Roberto Ulissi
Senior Vice President for Corporate Affairs and Governance
Raffaella Leone
Executive Assistant to the Chief Executive Officer

Eni Divisions Officers

EXPLORATION & PRODUCTION
Stefano Cao
General Manager
Guido Michelotti
Senior Vice President for the Kazakhstan project
Claudio Descalzi
Senior Vice President for Italy, Africa and Middle East
Gino Giannone
Senior Vice President for R&D
Sergio Palma
Senior Vice President for Reserves

  F. Arisi Rota
Senior Vice President for Exploration
Umberto Vergine
Senior Vice President for North Sea, Americas, Australasia, Russia
Stephen Prendergast
Coordinator LNG Development Team

GAS & POWER
Domenico Dispenza
General Manager
Marco Alverà
Senior Vice President for Supply and Portfolio Development
Francesco Caria
Senior Vice President for Sales to Business Italy
Laura Cioli
Senior Vice President for Retail Sales
Camillo M. Gloria
Senior Vice President for Sales outside Italy
Marco Toletti
Manager for Sales to Wholesalers Italy

REFINING & MARKETING
Angelo Taraborrelli
General Manager
Alberto Alberti
Senior Vice President Refining
Angelo Fanelli
Senior Vice President Marketing

ENGINEERING & CONSTRUCTION
Pietro Franco Tali
Chairman
Hugh O’ Donnell
Chief Executive Officer
Angelo Caridi
Director of Saipem SpA and Chief Executive Officer of Snamprogetti SpA
Jacques Yves Léost
Director of Saipem SpA and Chairman of Saipem SA

 

Board of Statutory Auditors

1. Paolo Andrea Colombo - Chairman

Statutory Auditors
2. Filippo Duodo
3. Edoardo Grisolia
4. Riccardo Perotta
5. Giorgio Silva
  External Auditors

PricewaterhouseCoopers SpA

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Remuneration
Remuneration earned for 2006 by members of the Board of Directors, General Managers and other managers with strategic responsibilities is reported in the table below.
  Remuneration earned by managers who held a position in 2006 for a fraction of the year is reported too.

(thousand euro)

Name  

Position (1)

Emoluments for service at Eni SpA

Non-cash benefits

Bonuses and other incentives (2)

 

Salaries and other elements

 

Total

BOARD OF DIRECTORS
                   
Roberto Poli  

Chairman

765

15

415

     

1,195

Paolo Scaroni  

CEO

430

62

834

 (3)

1,014

 

2,340

Alberto Clô Non-executive

Director

134

 

10

     

144

Renzo Costi Non-executive

Director

130

 

10

     

140

Dario Fruscio Non-executive

Director

124

 

10

     

134

Marco Pinto Non-executive

Director

130

 

10

     

140

Mario Resca Non-executive

Director

128

 

10

     

138

Marco Reboa Non-executive

Director

134

 

10

     

144

Pierluigi Scibetta Non-executive

Director

130

 

10

     

140

                   
GENERAL MANAGERS
                 
Stefano Cao

Exploration & Production

   

643

  966  

1,609

Domenico Dispenza

Gas & Power

   

386

  669  

1,055

Angelo Taraborrelli

Refining & Marketing

   

400

  645  

1,045

                 
Other managers with strategic responsibilities (4)      

1,932

 

7,846

 (5)

9,778

     
(1)   The term of position ends with the General Shareholders' Meeting approving financial statements for the year ending December 31, 2007.
(2)   Based on performance achieved in 2005.
(3)   Amount accrued related to the period of duration of the task from June 1 to December 31, 2005.
(4)   Managers, who during the year, have been members of the Eni Steering Committee with the CEO and the General Managers of Eni divisions (nine managers).
(5)   Includes also indemnities paid upon termination of employment contract.

 

Follows a description of each element of remuneration:
  • “Emoluments for service at Eni SpA” comprise fixed fees to non-executive and executive Directors for their office as Board member, the amount of which is set by shareholders. Fixed fees to the Chairman and the CEO for the powers delegated to them by the Board are also reported, the amount of which is set by the Board of Directors, based on proposals of the Compensation Committee and after consultation with the Board of Statutory Auditors. Furthermore, fixed fees to Directors attending the Committees formed by the Board of Directors are included this column;
  • “Non-cash benefits” comprise amounts referring to all fringe benefits, including insurance policies;
 
  • “Bonuses and other incentives” comprise: (i) the portion of fees linked to performance which was awarded in the year to Directors and the Chairman based on the performance of Eni share as compared with the performance of the seven largest international oil companies for market capitalization, taking account of the dividend paid; (ii) the portion of fees linked to performance which was awarded in the year to both the Chairman and the CEO in connection with the power delegated to them by the Board, based on the achievement of specific company objectives; and (iii) the portion of salaries linked to performance which was awarded in the year to the CEO, in his quality as employee of Eni, the General Managers of Eni’s divisions and other managers with strategic responsibilities based on the achievement of specific financial, operational and strategic targets and of individual performance goals pertaining to each business or functional unit;

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  • “Salaries and other elements” report base salaries paid to the CEO, the General Mangers of Eni’s divisions and other managers with strategic responsibilities, and indemnities paid upon termination of the employment contract.

Long-term incentive schemes
In March 2006, the Board of Directors approved a new long-term incentive scheme for senior managers of Eni Group companies (excluding listed subsidiaries), as proposed by the Compensation Committee.
This new scheme is intended to motivate more effectively and retain managers, linking incentives to targets and performance achieved in a tighter way than previous incentives schemes. This new incentive scheme applies to the 2006-2008 three year period and is composed of a deferred bonus, linked to the achievement of certain business growth and

  operating efficiency goals, and stock option awards based on the achievement of certain targets of total shareholder return. This scheme has a structure intended to balance monetary and stock-based components of the remuneration, as well as to link economic and operating performance to share performance in the long term.

Deferred bonus
This leg of the long-term incentive scheme envisages a basic bonus paid after three years according to a variable amount equal to a percentage ranging from 0 to 170% of the amount established for the target performance in relation to the performances achieved in a three-year period as approved by the Board of Directors. Performances are measured in terms of achievement of annual EBITDA targets preset for the 2006-2008 period, as assessed by comparing actual results with set targets under a constant trading environment for each year.
The following table sets out the basic bonus awarded in the year 2006 to the CEO and to the General Managers of Eni’s Divisions, and the total amount awarded to other managers with strategic responsibilities.

(thousand euro)

  NAME  

DEFERRED BONUS AWARDED   

     
Paolo Scaroni CEO

787

Stefano Cao General Manager of the E&P Division

468

Domenico Dispenza General Manager of the G&P Division

328

Angelo Taraborrelli General Manager of the R&M Division

307

Other managers with strategic responsibilities (1)  

1,293

     
(1)   No. 6 managers.

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Stock option plan
Eni offers managers of Eni Group companies holding positions of significant responsibility for achieving profitability or strategic targets, the opportunity to acquire a shareholding in the company as an element of remuneration through the award of options for purchasing Eni’s treasury shares.
Differently from previous schemes, the 2006-2008 stock option plan introduced a performance condition upon which options can be exercised.
At the end of each vesting period with a three-year duration, the Board of Directors determines the number of exercisable options, in a percentage ranging from 0% to 100% of the total amount awarded for each year of the plan, depending on the performance of Eni shares measured in terms of Total Shareholders Return as compared to that achieved
  by a panel of major international oil companies in terms of capitalization. On July 27, 2006, the Board of Directors approved: (i) the award pertaining to 2006 within the three-year period covered by the plan; (ii) its rule; and (iii) the criteria to be followed in the identification of eligible managers. Under this plan, 7,050,000 options were awarded pertaining to 2006 with a strike price equal to euro 23.119.

At December 31, 2006, a total of 15,290,400 options were outstanding for the purchase of an equal amount of ordinary shares nominal value euro 1 of Eni SpA, carrying an average strike price of euro 21.022.

The following is a summary of stock option activity for the years 2005 and 2006:

 

   

2005

 

2006

   
 
(euro)   Number of shares   Weighted average exercise price   Market price (a)   Number of shares   Weighted average exercise price   Market price (a)
                                     
Options as of January 1   11,789,00     15.111     18.461     13,379,600     17.705     23.460  
New options granted   4,818,500     22.512     22.512     7,050,000     23.119     23.119  
Options exercised in the period   (3,106,400 )   15.364     22.485     (4,943,200 )   15.111     23.511  
Options cancelled in the period   (121,500 )   16.530     23.100     (196,000 )   19.119     23.797  
Options outstanding as of December 31   13,379,600     17.705     23.460     15,290,400     21.022     25.520  
of which exercisable at December 31   1,540,600     16.104     23.460     1,622,900     16.190     25.520  
     
(a)   Market price relating to new rights assigned, rights exercised in the period and rights cancelled in the period corresponds to the average market value (arithmetic average of official prices recorded on Mercato Telematico Azionario in the month preceding: (i) the date of assignment; (ii) the date of the recording in the securities account of the managers to whom the options have been assigned; (iii) the date of the unilateral termination of employment for rights cancelled). Market price of shares referring to options as of the beginning and the end of the year, is the price recorded at December 31.

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Contents

ENI IN 2006 / DIRECTORS AND OFFICERS

The fair value of stock options granted during the years ended December 31, 2005, and 2006 of euro 3.33 and euro 2.89 respectively, was calculated applying the Black-Scholes method.   The following table presents the amount of stock options awarded to Eni’s CEO, General Managers and other managers with strategic responsibilities.

 

    CEO   General Manager E&P Division   General Manager G&P Division   General Manager R&M Division   Other managers with strategic responsibilities (1)
    Paolo Scaroni   Stefano Cao   Domenico Dispenza (2)   Angelo Taraborrelli    
   
 
 
 
 
                                 
Options outstanding at the beginning of the period:                                
- number of options       699,000     201,500   43,000   269,500  (3)   123,000   686,500
- average exercise price   (euro)   22.509     17.920   14.171   3.988     18.308   18.208
- average maturity in months       91     82   64   85     83   79
Options granted during the period:                                
- number of options       681,000  (4)   175,500   122,500   -     115,000   552,500
- average exercise price   (euro)   23.100     23.100   23.100   -     23.100   23.100
- average maturity in months       72     72   72   -     72   72
Options exercised at the end of the period:                                
- number of options       -     62,500   28,500   -     -   312,500
- average exercise price   (euro)   -     13.743   13.743   -     -   16.478
- average market price at date of exercise   (euro)   -     23.341   24.095   -     -   23.256
Options outstanding at the end of the period:                                
- number of options       1,380,000     314,500   137,000   269,500     238,000   926,500
- average exercise price   (euro)   22.801     21.641   22.244   3.988     20.624   21.709
- average maturity in months       73     70   65   73     68   69
       

 
 
 

 
 
     
(1)   No. 9 managers.
(2)   Appointed on January 1, 2006.
(3)   Options on Snam Rete Gas shares: assigned by the company to Domenico Dispenza who held the position of Chairman of Snam Rete Gas until December 23, 2005.
(4)   The assignment to the CEO has been integrated by a deferred bonus linked to the market performance of Eni shares, to be paid after a three year period and corresponding to 96,000 options with a strike price of euro 23.100 and a vesting period of three years.

 

Overall remuneration of key management personnel
On the whole, remuneration of persons responsible of key positions in planning, direction and control functions of Eni Group companies, including executive
  and non-executive directors, General Managers and other managers holding strategic responsibilities1 amounted to euro 23 million for 2006. The break-down is as follows

 

(million euro)

2006

Fees and salaries

16

Post employment benefits

1

Other long-term benefits

3

Fair value stock grants/options

3

 

23

 

     
(1)   These managers together with the CEO and the General Managers are permanent members of Eni’s Steering Committee.

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ENI IN 2006 / INVESTORS INFORMATION

Investor Information

ANNUAL GENERAL MEETING
The 2007 Annual General Shareholders’ Meeting is convened on May 23-24, 2007, on first and second call respectively, in Rome at one of Eni’s headquarters, Via del Serafico, 89/91, at 10:00 am (CET).

A notice convening the meeting is published on April 14, 2007, on the Official Gazette of the Republic of Italy and can be found at eni.it>Press Room>Notice in newspaper.

Beneficial Owners of ADRs, listed on the New York Stock Exchange, each ADR representing two Eni ordinary shares, who are recorded in Eni ADRs register of JPMorgan Chase Bank, N.A. by May 4, 2007 will be entitled to participate in the Meeting or to exercise votes by mail, after having complied with the deposit and registration requirements. Beneficial Owners who have taken advantage of Proxy Vote or Vote by Mail options are entitled to assist at the Meeting upon written request to be made to JPMorgan Chase Bank, N.A., ADRs Depositary.

Eni SpA’s Corporate Secretary is available for any further information Shareholders may need at the toll-free number 800 940 924 (for calls from abroad Italy: 80011223456) or fax number + 39 0659822233.

The Notice and the documentation regarding the Shareholders’ Meeting will be available on www.eni.it and may be requested by e-mail at segreteriasocietaria.azionisti@eni.it or by calling the above-mentioned toll-free numbers.
  DIVIDENDS
Eni announces dividends on its ordinary shares in terms of euro. In the Annual General Meeting, shareholders approve the dividend proposal made by the Board. For the fiscal year 2006, the Board proposed a dividend of euro 1.25 per share.
Eni paid an interim dividend for fiscal year 2006 amounting to euro 0.60 per share to shares on the register at the ex-dividend date (October 23, 2006). Following shareholders approval, the balance of euro 0.65 to the amount proposed by the Board is scheduled for June 21, 2007 (being the ex-dividend date June 18, 2007).
Holders of ADRs will receive euro 1.30 per ADR, payable on June 28, 2007 to ADR holders as of the June 20, 2007 record date.
Eni intends to continue paying interim dividends in the future.

Following Italian tax laws in force from January 1, 2004, dividends do not entitle to a tax credit and are either subject to a withholding tax or partially cumulated to the receiver’s taxable income, depending on the receiver fiscal status.
Holders of ADRs receive their dividends in US dollars. The rate of exchange used to determine the amount in dollars is equal to the official rate recorded on the date of dividend payment in Italy (June 21).
On ADR payment date, JPMorgan Chase Bank, N.A. pays the dividend less the amount of withholding tax under Italian law (currently 27%) to all Depository Trust Company Participants, representing payment of Eni SpA’s gross dividend.
Under a convention between the United States of America and Italy for the Avoidance of Double Taxation (“Treaty”), US residents who hold less than 10% of the Company, as defined in the Treaty, can effectively reduce the tax liability on dividends, from 27% to 15%. By submitting to JPMorgan Chase Bank, NA (“JPMorgan”) certain required documents with respect to each dividend payment, US holders of ADRs will enable the Italian Depositary bank and JPMorgan as ADR Depositary to pay the dividend at the reduced withholding tax rate of 15%.
US shareholders can obtain relevant documents as well as a complete instruction packet to benefit from this tax relief by contacting Eni’s Corporate Secretary or JPMorgan - Globe Tax Services at 1-800-929-5484.

 

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Contents

ENI IN 2006 / INVESTORS INFORMATION

1. Annual Report 2006 (www.eni.it/Investor Relations>Reports) a comprehensive report on Eni’s activities and results for the year.
2. Fact Book 2006 (www.eni.it/Investor Relations>Reports), a report on Eni’s businesses, strategies, objectives and development projects.
3. Sustainability Report 2006 (www.eni.it/Sustainability>Eni’s Documents) provides readers with a thorough presentation of Eni’s commitment to the global sustainability issue. It describes the main interactions of Eni’s activities on human resources, the environment, communities and the territory, focusing on improvement targets and results achieved.
4. The World Oil and Gas Review (www.eni.it/Publications>Economic and Energy Analyses) provides economic and energy historical series of the World Energy and Economic Atlas. Readers can use and aggregate individual statistics. The review is available in both full and abridged versions, and downloadable as a pdf file. Requests for printed copies should be made to: worldoil&gasreview@eni.it
5. Code of Practice (www.eni.it/Publications>Corporate Responsibility). Information regarding Eni’s Corporate Governance guidelines as well as Eni’s By-laws and charts of the Board’s Committees can be found in www.eni.it/The Company>Corporate Governance.
These and other Eni publications are available on Eni’s internet site www.eni.it, in the section Documents Download. Shareholders may receive a hard copy of Eni’s publications, free of charge, by filling in the request form found in the section Documents Download or through an email request addressed to segreteriasocietaria.azionisti@eni.it or to investor.relations@eni.it.
Any other information relevant to shareholders and investors can be found at Eni’s website under the “Investor Relations” section.

 

FINANCIAL CALENDAR
The dates of the Board of Directors’ Meetings to be held during 2007 in order to approve/review the Company’s financial accounts are the following:
  • Report on the first quarter of 2007
  • Report on the second quarter of 2007
  • Report on the first half 2007 and proposal of interim dividend for the financial year 2007
  • Report on the third quarter of 2007
  • Report on the fourth quarter of 2007, Preliminary results for the year 2007 and Dividend proposal for the financial year 2007

May 10, 2007

July 25, 2007


September 20, 2007

November 8, 2007


February 2008

Related press releases are normally issued on the following day the event.

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Contents

 

 
   
  Società per Azioni
Headquarters: Rome, Piazzale Enrico Mattei, 1
Capital stock:
euro 4,005,358,876 fully paid
Tax identification number 00484960588
Branches:
San Donato Milanese (MI) - Via Emilia, 1
San Donato Milanese (MI) - Piazza Ezio Vanoni, 1
 

CONTACTS
E-mail:
segreteriasocietaria.azionisti@eni.it

Investor Relations
E-mail: investor.relations@eni.it
Tel. +39-0252051651 - Fax +39-0252031929

Eni Press Office
E-mail:
ufficiostampa@eni.it
Tel.: +39 0252031287 - +39 0659822040


ADRs/Depositary
Morgan Guaranty Trust Company of New York
ADR Department
60 Wall Street (36th Floor)
New York, New York 10260
Tel.: 212 648 3164

ADRs/Transfer agent
Morgan ADR Service Center
2 Heritage Drive
North Quincy, MA 02171
Tel.: 617 575 4328

Design: Apr - Rome - Italy
Cover: Grafica Internazionale - Rome - Italy
Layout and supervision: Korus Srl - Rome - Italy
Printing: Marchesi Grafiche Editoriali - Rome - Italy
Printed on environmental frindly paper:
Fedrigoni Symbol
Freelife Satin and Freelife Vellum

 


Contents


Table of Contents
Contents


Table of Contents

Report on the first quarter
of 2007

 


Contents

   

1

  Statistic recap
   

2

  Basis of presentation

Financial review

 

3

  Profit and loss account and divisional highlights
   

5

  Analysis of profit and loss account items
   

11

  Summarized group balance sheet
   

16

  Summarized cash flow statement and change in net borrowings
   

17

  Capital expenditure
    20   Post closing events
   

22

  Outlook for 2007

Operating results by division

 

23

  Exploration & Production
   

25

  Gas & Power
   

29

  Refining & Marketing
   

31

  Petrochemicals
   

32

  Engineering & Construction

Non-GAAP measures

 

34

  Reconciliation of reported operating profit and net profit to results on an adjusted basis

 

 


Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

STATISTIC RECAP

Summary financial data

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
21,416   Net sales from operations       23,584     21,913     (1,671 )   (7.1 )
3,957   Operating profit       5,595     5,105     (490 )   (8.8 )
4,776   Adjusted operating profit (a)       5,533     5,253     (280 )   (5.1 )
1,520   Net profit (b)       2,974     2,588     (386 )   (13.0 )
0.41   - per ordinary share (euro) (c)       0.80     0.70     (0.10 )   (12.5 )
1.06   - per ADR ($) (b) (c)       1.92     1.83     (0.09 )   (4.7 )
2,355   Adjusted net profit (a) (b)       2,954     2,680     (274 )   (9.3 )
0.64   - per ordinary share (euro) (b)       0.79     0.73     (0.06 )   (7.6 )
1.65   per ADR ($) (b) (c)       1.90     1.91     0.01     0.5  
1,778   Net cash provided by operating activities       5,863     5,563     (300 )   (5.1 )
2,944   Capital expenditure       1,340     2,013     673     50.2  
     
(a)   For a detailed explanation of adjusted operating profit and adjusted net profit see page 34.
(b)   Profit attributable to Eni shareholders.
(c)   Fully diluted. Dollar amounts are converted on the basis of the average EUR/USD exchange rate quoted by the ECB for the periods presented.
(d)   One ADR (American Depositary Receipt) is equal to two Eni ordinary shares.

 

Key market indicators

Fourth Quarter

     

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
59.68   Average price of Brent dated crude oil (a)       61.75     57.75     (4.00 )   (6.5 )
1.290   Average EUR/USD exchange rate (b)       1.202     1.310     0.108     9.0  
46.26   Average price in euro of Brent dated crude oil       51.37     44.08     (7.29 )   (14.2 )
2.18   Average European refining margin (c)       2.95     3.06     0.11     3.7  
1.69   Average European refining margin in euro       2.45     2.34     (0.11 )   (4.5 )
3.6   Euribor - three month rate (%)       2.6     3.8     1.2     46.2  
5.3   Libor - three month dollar rate (%)       4.7     5.3     0.6     12.8  
     
(1)   In USD per barrel. Source: Platt’s Oilgram.
(2)   Source: ECB.
(3)   In USD per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations based on Platt’s Oilgram data.

 

Summary operating data

Fourth Quarter

     

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,796   Production of hydrocarbons (a)   (kboe/d)   1,827     1,734     (93 )   (5.1 )
1,079   Liquids   (kbbl/d)   1,143     1,030     (113 )   (9.9 )
4,132   Natural gas (a)   (mmcf/d)   3,920     4,061     141     3.6  
26.93   Worldwide gas sales   (bcm)   31.20     28.14     (3.06 )   (9.8 )
1.06   of which: upstream sales in Europe       1.12     1.07     (0.05 )   (4.5 )
7.79   Electricity sold   (TWh)   7.73     7.61     (0.12 )   (1.6 )
3.13   Retail sales of refined products in Europe   (mmtonnes)   2.93     2.88     (0.05 )   (1.7 )
1,323   Petrochemical product sales   (ktonnes)   1,411     1,417     6     0.4  
     
(1)   Includes own consumption of natural gas (51 kboe/d in the first quarter of 2007, 48 kboe/d in the first quarter of 2006 and 50 kboe/d in the fourth quarter of 2006).

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

BASIS OF PRESENTATION
Eni’s accounts at March 30, 2007, unaudited, have been prepared in accordance with the criteria defined by the Commissione Nazionale per le Società e la Borsa (CONSOB) in its regulation for companies listed on the Italian Stock Exchange.
Financial information relating to the profit and loss account are presented for the first quarter of 2007 and for the first and fourth quarter of 2006. Financial information relating to balance sheet data are presented at March 31, 2007, March 31, 2006 and December 31, 2006. Tables are comparable with those of 2006 financial statements and first half report.
Eni’s accounts at March 31, 2007 have been prepared in accordance with the evaluation and measurement criteria contained in the International Financial Reporting Standards (IFRS) issued by the International Accounting Standards Board (IASB) and adopted by the European Commission according to the procedure set forth in Article 6 of the European Regulation (CE) No. 1606/2002 of the European Parliament and European Council of July 19, 2002.
Non-GAAP financial measures disclosed throughout this report are accompanied by explanatory notes and tables to help investors to gain a full understanding of said measures in line with guidance provided for by recommendation CESR/05-178b.
  Disclaimer
This report contains certain forward-looking statements, in particular in the Outlook section those regarding capital expenditure, dividends, share repurchases, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets, and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply, demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors.

Due to the seasonality in demand for natural gas and certain refined products and the changes in a number of external factors affecting Eni’s operations, such as prices and margins of hydrocarbons and refined products, Eni’s results of operations and changes in average net borrowings for the first quarter of the year cannot be extrapolated for the full year.

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

 

Financial review

PROFIT AND LOSS ACCOUNT AND DIVISIONAL HIGHLIGHTS

 

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

21,416     Net sales from operations   23,584     21,913     (1,671 )   (7.1 )
302     Other income and revenues   209     281     72     34.4  
(15,874 )   Operating expenses   (16,739 )   (15,462 )   1,277     7.6  
(182 )   of which non-recurring items                        
(1,887 )   Depreciation, amortization and impairments   (1,459 )   (1,627 )   (168 )   (11.5 )
3,957     Operating profit   5,595     5,105     (490 )   (8.8 )
52     Net financial income (expense)   42     (133 )   (175 )   ..  
157     Net income from investments   240     202     (38 )   (15.8 )
4,166     Profit before income taxes   5,877     5,174     (703 )   (12.0 )
(2,468 )   Income taxes   (2,747 )   (2,431 )   316     11.5  
59.2     Tax rate (%)   46.7     47.0     0.3        
1,698     Net profit   3,130     2,743     (387 )   (12.4 )
      pertaining to:                        
1,520     - Eni   2,974     2,588     (386 )   (13.0 )
178     - minority interest   156     155     (1 )   (0.6 )

 

Eni’s net profit for the first quarter of 2007 was euro 2,588 million, down euro 386 million from the first quarter of 2006, or 13.0%, due essentially to a lower operating performance (down euro 490 million, or 8.8%) as result of a decline in the Exploration & Production division, partially offset by a   positive performance delivered by Eni‘s downstream and the Engineering & Construction businesses. This reduction in net profit was also due to higher net financial expenses mainly owing to losses on the fair value evaluation of certain financial derivative instruments.

 

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

1,520     Net profit pertaining to Eni   2,974     2,588     (386 )   (13.0 )
213     Exclusion of inventory holding (gain) loss   (59 )   97     156        
622     Exclusion of special items:   39     (5 )   (44 )      
      of which:                        
184     - non-recurring items                        
438     - other special items   39     (5 )   (44 )      
2,355     Eni's adjusted net profit (a)   2,954     2,680     (274 )   (9.3 )
     
(a)   For a definition and reconciliation of reported operating profit and reported net profit to adjusted results, which exclude inventory holding gains/losses and special items, “Reconciliation of reported operating profit and net profit to results on an adjusted basis” page 34.

 

Eni’s adjusted net profit amounted to euro 2,680 million, down 9.3% from the first quarter 2006. Adjusted net profit is arrived at by excluding an inventory holding loss of euro 97 million and special income of euro 5 million net.

Special charges concerned essentially environmental charges and employee redundancy incentives, offset by a gain from the settlement reached by Syndial and Dow
  Chemical on some contractual issues pending between the two companies.

Return on Average Capital Employed (ROACE) calculated on an adjusted basis for the twelve-month period ending March 31, 2007 was 22.7% (21.8% for the twelve-month period ending March 31, 2006).

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

The trading environment was affected by lower oil prices with Brent crude prices averaging $57.75 per barrel, down 6.5% compared to the first quarter of 2006, and the appreciation of the euro over the dollar (up 9.0%). These negatives were partially offset by: (i) favorable trends in   energy and exchange rate parameters used in determining purchase and selling prices of natural gas; (ii) an increase in refining margins on the Brent crude marker (up 3.7%), and (iii) higher sales margins on petrochemical products.

The following table sets forth adjusted net profit1 by division:

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

1,304     Exploration & Production   2,095     1,409     (686 )   (32.7 )
873     Gas & Power   879     1,159     280     31.9  
115     Refining & Marketing   86     113     27     31.4  
141     Petrochemical   16     79     63     393.8  
131     Engineering & Construction   87     145     58     66.7  
(85 )   Other activities   (58 )   (50 )   8     (13.8 )
57     Corporate and financial companies   6     (86 )   (92 )   ..  
(3 )   Impact of unrealized profit in inventory (a)   (1 )   66     67     ..  
2,533         3,110     2,835     (275 )   (8.8 )
      of which:                        
178     Net profit of minorities   156     155     1     (0.6 )
2,355     Eni's adjusted net profit   2,954     2,680     (274 )   (9.3 )
     
(a)   Unrealized profit in inventory concerned intra-group sales of goods and services recorded at period end in the equity of the purchasing business segment.

 

The decline in the Group adjusted net profit was owed to the reduction of adjusted net profit registered in the Exploration & Production division (down euro 686 million or 32.7%), due to a weaker operating performance (down euro 1,119 million or 26.3%) which was adversely impacted by the appreciation of the euro over the dollar (up 9.0%), a decline in production sold (down 9.5 mmboe/d), lower oil realizations in dollars (oil down 3.3%), and higher exploration expenses.

The decline in the adjusted net profit of the Exploration & Production division was partly offset by a higher adjusted net profit reported in the divisions:
- Gas & Power (up euro 280 million or 31.9%), as a result of an improved operating performance (up euro 480 million or 40%) reflecting higher natural gas selling margins supported mainly by a favorable trading environment, relating in particular to trends in the euro vs dollar exchange rate. This divisional performance
  benefited also from a positive evolution of the regulatory framework in Italy. These positives were partly offset by lower natural gas sales (down 2.87 bcm or 10.4%) hurt by lower European gas demand due to the unusually mild weather conditions registered in the first quarter 2007;
- Refining & Marketing (up euro 27 million or 31.4%), reflecting an improved refining performance boosted by higher processed volumes and better yields also in light of lower maintenance shutdowns;
- Petrochemical (up euro 63 million, or 393.8%), due to an improved operating performance (up euro 99 million) reflecting a recovery in product selling margins;
- Engineering & Construction (up euro 58 million, or 66.7%) reflecting an improved operating performance (up euro 98 million) against the backdrop of favorable demand trends in oilfield services.

 

 

     
(1)   For a definition and reconciliation of reported operating profit and reported net profit to adjusted results, which exclude inventory holding gains/losses and special items, “Reconciliation of reported operating profit and net profit to results on an adjusted basis” page 32.

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

ANALYSIS OF PROFIT AND LOSS ACCOUNT ITEMS

Net sales from operations

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

6,152     Exploration & Production   7,412     6,361     (1,051 )   (14.2 )
8,170     Gas & Power   9,134     8,543     (591 )   (6.5 )
8,579     Refining & Marketing   9,280     7,943     (1,337 )   (14.4 )
1,740     Petrochemical   1,728     1,674     (54 )   (3.1 )
1,969     Engineering & Construction   1,310     1,962     652     49.8  
161     Other activities   214     57     (157 )   (73.4 )
345     Corporate and financial companies   307     282     (25 )   (8.1 )
(5,700 )   Consolidation adjustment   (5,801 )   (4,909 )   892        
21,416         23,584     21,913     (1,671 )   (7.1 )

 

Eni’s net sales from operations (revenues) for the first quarter of 2007 (euro 21,913 million) were down euro 1,671 million, a 7.1% decline from the first quarter of 2006, primarily reflecting the impact of the appreciation of the euro versus the dollar (up 9%) and the decline in oil prices, as well as sold production of hydrocarbons and natural gas sales. These negative factors were offset in part by higher activity levels in the Engineering & Construction segment and higher gas prices.

Revenues generated by the Exploration & Production segment (euro 6,361 million) declined by euro 1,051 million, down 14.2%, essentially due to the impact of the appreciation of the euro versus the dollar and the decline in oil realizations in dollars (down 3.3%) and lower hydrocarbon production sold (down 9.5 million boe). These factors were offset in part by higher gas prices (up 1.3%).

Revenues generated by the Gas & Power segment (euro 8,543 million) declined by euro 591 million, down 6.5%, essentially due to lower natural gas volumes sold by consolidated subsidiaries (down 2.87 billion cubic meters or 10.4%) and lower volumes transported and distributed as a consequence of an unusually mild winter.
  These negative factors were offset in part by increased natural gas prices, related in particular to trends of energy parameters to which gas prices are contractually indexed.

Revenues generated by the Refining & Marketing segment (euro 7,943 million) declined by euro 1,337 million, down 14.4%, essentially due to lower international prices for oil and refined products and the effect of the appreciation of the euro over the dollar. An additional negative factor was the decline in volumes marketed on retail and wholesale markets in Italy (down 410 ktonnes, or 8%) related to the competitive pressure and a mild winter that reduced the demand for heating oil.

Revenues generated by the Petrochemical segment (euro 1,674 million) were substantially stable from the first quarter of 2006.

Net sales from operations generated by the Engineering & Construction segment (euro 1,962 million) increased by euro 652 million, up 49.8%, due to increased activity levels in the Offshore and Onshore construction business.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Revenues by geographic area

  

 

(million euro)

 

First quarter

        

  

     

2006

 

2007

 

Change

 

% Ch.

Italy   11,118     9,711     (1,407 )   (12.7 )
Rest of European Union   5,528     5,146     (382 )   (6.9 )
Rest of Europe   2,118     1,808     (310 )   (14.6 )
Americas   1,479     1,326     (153 )   (10.3 )
Asia   1,339     1,678     339     25.3  
Africa   1,768     2,048     280     15.8  
Other areas   234     196     (38 )   (16.2 )
Total outside Italy   12,466     12,202     (264 )   (2.1 )
    23,584     21,913     (1,671 )   (7.1 )

Operating expenses

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

14,897     Purchases, services and other   15,912     14,584     (1,328 )   (8.3 )
      of which:                        
184     - non-recurring items                        
115     - other special items   5     17     12        
977     Payroll and related costs   827     878     51     6.2  
      of which:                        
101     - provision for redundancy incentives   24     10     (14 )      
15,874         16,739     15,462     (1,277 )   (7.6 )

 

Operating expenses for the first quarter of 2007 (euro 15,462 million) declined by euro 1,277 million from the first quarter of 2006, down 7.6%, essentially due to: (i) lower prices for oil-based and petrochemical feedstocks and for natural gas reflecting an appreciation of the euro versus the dollar; (ii) lower supplies of natural gas in line with lower sales and the fact that in the first quarter of 2006 higher gas supplies costs were recorded due to a climatic emergency; (iii) lower costs for refinery maintenance activity.   Labor costs (euro 878 million) increased by euro 51 million, up 6.2%, due mainly to an increase in unit labor cost in Italy and outside Italy and an increase in the average number of employees outside Italy in the Engineering & Construction segment related to higher activity levels.

Employees

  

 

(units)

 

Dec. 31, 2006

 

Mar. 31, 2007

 

Change

 

% Ch.

Exploration & Production   8,336     8,432     96     1.2  
Gas & Power   12,074     11,957     (117 )   (1.0 )
Refining & Marketing   9,437     9,384     (53 )   (0.6 )
Petrochemical   6,025     6,876     851     14.1  
Engineering & Construction   30,902     31,661     759     2.5  
Other activities   2,219     1,447     (772 )   (34.8 )
Corporate and financial companies   4,579     4,775     196     4.3  
    73,572     74,532     960     1.3  

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ENI REPORT ON THE FIRST QUARTER OF 2007

As of March 31, 2007, employees were 74,532, with an increase of 960 employees from December 31, 2006, up 1.3%.
Employees in Italy were 39,878. The 113 employee increase was related mainly to the positive balance of hiring and dismissals (79 employees) related to changes in consolidation.
  In the first quarter of 2007 a total of 540 employees were hired, of these 375 on open-end contracts and 461 employees were dismissed (of these 281 employees on open-end contracts).
Outside Italy employees were 34,654, with a 847 employee increase mainly concerning fixed-term workers in the Engineering & Construction segment.

Depreciation, amortization and impairments

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

1,418     Exploration & Production   1,095     1,240     145     13.2  
185     Gas & Power   162     166     4     2.5  
101     Refining & Marketing   110     108     (2 )   (1.8 )
33     Petrochemical   31     31              
56     Engineering & Construction   38     63     25     65.8  
2     Other activities   2     1     (1 )   (50.0 )
21     Corporate and financial companies   19     16     (3 )   (15.8 )
(7 )   Impact of unrealized profit in inventory   (1 )   (1 )            
1,809     Total depreciation and amortization   1,456     1,624     168     11.5  
78     Impairments   3     3              
1,887         1,459     1,627     168     11.5  

 

Depreciation and amortization charges (euro 1,624 million) increased by euro 168 million, up 11.5%, mainly in the Exploration & Production segment (euro 145 million) related to higher exploration costs and higher amortization   charges for site restoration and abandonment costs related to a revision of cost estimates carried out when closing 2006 accounts.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Operating profit

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change

 

% Ch.

3,957     Operating profit   5,595     5,105     (490 )   (8.8 )
341     Exclusion of inventory holding (gains) losses   (94 )   155     249        
478     Exclusion of special items:   32     (7 )   (39 )      
      of which:                        
184     - non-recurring items                        
294     - other special items   32     (7 )   (39 )      
4,776     Adjusted operating profit   5,533     5,253     (280 )   (5.1 )
      Break down by division:                        
3,195     Exploration & Production   4,251     3,132     (1,119 )   (26.3 )
1,269     Gas & Power   1,203     1,683     480     39.9  
148     Refining & Marketing   89     120     31     34.8  
154     Petrochemical   23     122     99     430.4  
152     Engineering & Construction   78     176     98     125.6  
(77 )   Other activities   (63 )   (50 )   13     20.6  
(53 )   Corporate and financial companies   (46 )   (35 )   11     23.9  
(12 )   Effect of unrealized profit in inventory   (2 )   105     107     ..  
4,776         5,533     5,253     (280 )   (5.1 )

 

Adjusted operating profit was euro 5,523 million, down 5.1% from a year ago. Adjusted net profit is arrived at by excluding an inventory holding loss of euro 155 million and special income of euro 7 million net. The main factors affecting this decline were the operating performance of the Exploration & Production division (down euro 1,119 million from the first quarter 2006, or 26.3%), due primarily to the 9% appreciation of the euro versus the dollar, lower production sold (down 9.5 mmboe), lower oil realizations in dollars (down 3.3%) and higher expenses incurred in connection with exploratory activity.
These declines were partly offset by an increase in adjusted operating profit in the following segments:
(i) Gas & Power (up euro 480 million or 39.9%), reflecting primarily increased natural gas selling margins mainly owing to a favorable trading environment, relating in particular to trends in the euro vs dollar exchange rate.
  A favorable evolution of the regulatory framework in Italy also supported operating profit. These positives were partly offset by a decline in natural gas sales (down 2.87 bcm, or 10.4%) due to lower European gas demand as a consequence of the unusually mild weather conditions of the first quarter 2007, partly offset by a growth in sales in certain target markets in the rest of Europe; (ii) Petrochemical (up euro 99 million or 430.4%) related to an increase in selling margins; (iii) Engineering & Construction (up euro 98 million or 125.6%) due to a positive trend in the market for oilfield services; (iv) Refining & Marketing (up euro 31 million or 34.8%) reflecting primarily a better operating performance delivered by the refining activity, which was boosted by higher processed volumes and better yields also in light of lower maintenance shutdowns.

 

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ENI REPORT ON THE FIRST QUARTER OF 2007

Net financial expense
In the first quarter of 2007 net financial expense (euro 133 million) increased by euro 175 million from the first quarter of 2006. This increase was due to: (i) losses recognized on the fair value evaluation of certain financial derivatives instruments recorded in the profit and loss account instead of being recognized in connection with related assets, liabilities and commitments because these instruments do not meet the formal criteria to
  lbe assessed as hedge under IFRS, including the time value component of certain cash flow hedges Eni entered into to hedge risk on commodities in the quarter (see comment to net working capital below); (ii) the impact of higher interest rates on euro (Euribor up 1.2 percentage points) and dollar loans (Libor up 0.6 percentage points), offset in part by a decline in average net borrowings.

Net income from investments

First Quarter 2007

(million euro)

  Exploration & Production   Gas & Power   Refining & Marketing   Engineering & Construction   Group
Effect of the application of the equity method of accounting   9     114     36     26     185  
Dividends   3     1     15           19  
Other income (losses) from investments   (2 )                     (2 )
    10     115     51     26     202  

 

Net income from investments in the first quarter of 2007 amounted to euro 202 million and concerned essentially: (i) Eni’s share of income of affiliates accounted for with the equity method of accounting (euro 185 million), in particular in the Gas & Power, Refining & Marketing and   Engineering & Construction division; (ii) dividends received by affiliates accounted for at cost (euro 19 million).

The comparison with the first quarter 2006 data is shown in the table below:

 

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change


     
 
 
164     Effect of the application of the equity method of accounting   187     185     (2 )
4     Dividends   27     19     (8 )
(3 )   Net gains on disposal   18           (1 )
(8 )   Other income (losses) from investments   8     (2 )   (1 )
157         240     202     (38 )

 

The euro 38 million decrease in net income from investments was due essentially to lower results reported by   certain affiliates engaged in natural gas distribution in Italy, due to mild weather conditions.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Income taxes

Fourth Quarter

 

(million euro)

 

First Quarter


     

2006

     

2006

 

2007

 

Change


     
 
 
      Profit before income taxes                  
1,105     Italy   1,903     2,007     104  
3,061     Outside Italy   3,974     3,167     (807 )
4,166         5,877     5,174     (703 )
      Income taxes                  
480     Italy   729     792     63  
1,988     Outside Italy   2,018     1,639     (379 )
2,468         2,747     2,431     (316 )
      Tax rate (%)                  
43.4     Italy   38.3     39.5     1.2  
64.9     Outside Italy   50.8     51.8     1.0  
59.2         46.7     47.0     0.3  

 

Income taxes were euro 2,431 million, down euro 316 million, or 11.5%, due primarily to lower income before taxes (down euro 703 million). The 47% Group tax rate is substantially in line with that of the first quarter of 2006.
Adjusted tax rate, obtained from the ratio of taxes and profit before taxes net of inventory holding gains (losses) and special charges was 46.7% (46.5% in the first quarter of 2006).
  Minority interests
Minority interests
were euro 155 million and concerned primarily Snam Rete Gas SpA (euro 69 million) and Saipem (euro 78 million).

 

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ENI REPORT ON THE FIRST QUARTER OF 2007

SUMMARIZED GROUP BALANCE SHEET

Summarized group balance sheet aggregates the amount of assets and liabilities derived from the statutory balance sheet in accordance with functional criteria which consider the enterprise conventionally divided into the three fundamental areas focusing on resource investments, operations and financing.
Management believes that this summarized group balance sheet is useful information in assisting investors to
  assess Eni's capital structure and to analyze its sources of funds and investments in fixed assets and working capital.
Management uses the summarized group balance sheet to calculate key ratios such as return on capital employed (ROACE) and the proportion of net borrowings to shareholders' equity (leverage) intended to evaluate whether Eni's financing structure is sound and well-balanced.

 

Summarized group balance sheet (a)

       

(million euro)

  Dec. 31, 2006   Mar. 31, 2007   Change
   
 
 
Fixed assets                  
Property, plant and equipment, net   44,312     44,435     123  
Other tangible assets   629     622     (7 )
Inventories - compulsory stock   1,827     1,711     (116 )
Intangible assets, net   3,753     3,885     132  
Investments, net   4,246     4,373     127  
Accounts receivable financing and securities related to operations   557     515     (42 )
Net accounts payable in relation to capital expenditure   (1,090 )   (897 )   193  
    54,234     54,644     410  
Net working capital                  
Inventories   4,752     4,888     136  
Trade accounts receivable   15,230     15,006     (224 )
Trade accounts payable   (10,528 )   (9,692 )   836  
Taxes payable and reserve for net deferred income tax liabilities   (5,396 )   (7,306 )   (1,910 )
Reserve for contingencies   (8,614 )   (8,335 )   279  
Other operating assets and liabilities (b)   641     (1,230 )   (589 )
    (5,197 )   (6,669 )   (1,472 )
Employee termination indemnities and other benefits   (1,071 )   (1,032 )   39  
Capital employed, net   47,966     46,943     (1,023 )
Shareholders' equity including minority interests   41,199     43,091     1,892  
Net borrowings   6,767     3,852     (2,915 )
Total liabilities and shareholders' equity   47,966     46,943     (1,023 )
     
(a)   For a reconciliation with the corresponding statutory tables see Eni’s 2006 Annual Report, “Reconciliation of Summarized Group Balance Sheet to statutory schemes” pages 77-78.
(b)   Include operating financing receivables and securities related to operations for euro 220 million (euro 249 million at December 31, 2006) and securities covering technical reserves of Eni’s insurance activities for euro 451 million (euro 417 million at December 31, 2006).

 

The appreciation of the euro over other currencies, in particular the dollar (at March 31, 2007 the EUR/USD exchange rate was 1.332 as compared to 1.317 at December 31, 2006, up 1.1%) determined with respect to year-end 2006 an estimated decrease in the book value of net capital employed of approximately euro 300 million, in net equity of approximately euro 250 million   and in net borrowings of approximately euro 50 million as a result of currency conversions at March 31, 2007.

At March 31, 2007, net capital employed totalled euro 46,943 million, representing a decrease of euro 1,023 million from December 31, 2006.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Fixed assets totalled euro 54,644 million, representing an increase of euro 410 million from December 31, 2006 (euro 54,234 million). Capital expenditure for the period (euro 2,013 million) was offset in part by provisions for depreciation, amortization and impairments (euro 1,627 million) and the effect of the appreciation of the euro over the dollar in the translation of financial statements of subsidiaries operating with currencies other than the euro.

Other assets included, for a book value of $829 million (corresponding to euro 622 million at the March 31, 2007 EUR/USD exchange rate), the assets related to the service contract for oil activities in the Dación area of the Venezuelan branch of Eni's subsidiary Eni Dación BV. With effective date April 1, 2006, the Venezuelan State oil company Petróleos de Venezuela SA (PDVSA) unilaterally terminated the Operating Service Agreement (OSA) governing activities at the Dación oil field where Eni acted as a contractor, holding a 100% working interest. As a consequence, starting on the same date, operations at the Dación oil field are conducted by PDVSA. Eni proposed to PDVSA to agree on terms in order to recover the fair value of its Dación assets. On November 2006, based on the bilateral investments treaty in place between the Netherlands and Venezuela (the “Treaty”), Eni commenced a proceeding before an International Centre for Settlement of Investment Disputes (ICSID) Tribunal (i.e., a tribunal acting under the auspices of the ICSID Convention and being competent pursuant to the Treaty) to claim its rights. Despite this action, Eni is still ready to negotiate a solution with PDVSA to obtain a fair compensation for its assets. Based on the opinion of its legal consultants, Eni believes to be entitled to a compensation for such expropriation in an amount equal to the market value of the OSA before the expropriation took place. The market value of the OSA depends upon its expected profits. In accordance with established international practice, Eni has calculated the OSA’s market value using the discounted cash flow method, based on Eni’s interest in the expected future hydrocarbon production and associated capital expenditures and operating costs, and applying to the projected cash flow a discount rate reflecting Eni’s cost of capital as well as the specific risk of concerned activities. Independent evaluations carried out by a primary petroleum consulting firm fully support Eni’s internal evaluation. The estimated net present value of Eni’s interest in the Dación
  field, as calculated by Eni, is higher than the net book value of the Dación assets which consequently have not been impaired. In accordance with the ICSID Convention, a judgement by the ICSID Tribunal awarding compensation to Eni would be binding upon the parties and immediately enforceable as if it were a final judgement of a court of each of the States that have ratified the ICSID Convention. The ICSID Convention was ratified in 143 States. Accordingly, if Venezuela fails to comply with the award and to pay the compensation, Eni could take steps to enforce the award against commercial assets of the Venezuelan Government almost anywhere those may be located (subject to national law provisions on sovereign immunity).

At March 31, 2007, net working capital totalled euro 6,669 million, representing a decrease of euro 1,472 million from December 31, 2006 mainly due to: (i) higher taxes payable and an increase in reserves for taxation related to taxes due for the period and the fact that excise taxes on oil products marketed in Italy in the first 15 days of December are settled within the end of this month, instead of being paid in the following month as in the rest of the year; (ii) the increase in Other operating liabilities related to a euro 575 million loss recognized on the fair value evaluation of certain financial derivative instruments. The Group entered into such transactions in order to hedge cash flow expected in the 2008-2011 period from the sale of approximately 2% of Eni’s proved hydrocarbon reserves as of 2006 year-end in connection with its purchase of proved and unproved property onshore in Congo (from the French company Maurel & Prom) and in the Gulf of Mexico (from the US company Dominion) finalized in February and April 2007, respectively. In light of this, Eni put in place certain forward sale contracts at a fixed price and call and put options with the same date of exercise. These options can be exercised in presence of crude oil market prices higher or lower compared with contractual prices. This treatment does not apply to the time value component arising from market price fluctuations within the range provided by these call and put options which is recognized in the profit and loss account under the item net financial expenses because the hedging relationship is ineffective.
The share of the Exploration & Production, Gas & Power and Refining & Marketing divisions on net capital employed was 89% (90% at December 31, 2006).

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ENI REPORT ON THE FIRST QUARTER OF 2007

Return On Average Capital Employed (ROACE)

Return on Average Capital Employed for the Group, on an adjusted basis is the return on the Group average capital invested, calculated as the ratio between net adjusted profit before minority interest, plus net finance charges on net borrowings net of the related tax effect, and net average capital employed. The tax rate applied on finance charges is the Italian statutory tax rate of 33%. The capital invested as of period-end used for the calculation of net average capital invested is   obtained by deducting inventory holding gains or losses for the period, net of the related tax effect.
ROACE by business segment is determined as the ratio between adjusted net profit and net average capital invested pertaining to each business segment, adjusting net capital invested as of period-end by net inventory gains or losses (net of the related tax effect based on each business segment specific tax rate).

 

Calculated on a 12-month period ending on                                     (million euro)   Exploration &   Gas &   Refining &   Group
March 31, 2007   Production   Power   Marketing    









Adjusted net profit   6,593   3,142   656   10,743  
Exclusion of after-tax finance expenses/interest income               50  
Adjusted net profit unlevered   6,593   3,142   656   10,793  
Capital employed, net                  
- at the beginning of period   19,702   17,656   5,556   47,843  
- at the end of period   17,143   18,985   5,830   47,132  
Average capital employed, net   18,423   18,321   5,693   47,488  
ROACE adjusted (%)   35.8   17.2   11.5   22.7  

 

Calculated on a 12-month period ending on                                     (million euro)   Exploration &   Gas &   Refining &   Group
March 31, 2006   Production   Power   Marketing    









Adjusted net profit   6,931   2,427   908   10,303  
Exclusion of after-tax finance expenses/interest income               (80 )
Adjusted net profit unlevered   6,931   2,427   908   10,223  
Capital employed, net                  
- at the beginning of period   18,708   18,283   4,247   46,623  
- at the end of period   19,702   17,590   4,950   47,147  
Average capital employed, net   19,205   17,937   4,599   46,885  
ROACE adjusted (%)   36.1   13.5   19.7   21.8  

 

Calculated on a 12-month period ending on                                     (million euro)   Exploration &   Gas &   Refining &   Group
December 31, 2006   Production   Power   Marketing    









Adjusted net profit   7,279   2,862   629   11,018  
Exclusion of after-tax finance expenses/interest income               46  
Adjusted net profit unlevered   7,279   2,862   629   11,064  
Capital employed, net                  
- at the beginning of period   20,206   18,978   5,993   49,692  
- at the end of period   18,590   18,864   5,766   47,999  
Average capital employed, net   19,398   18,921   5,880   48,846  
ROACE adjusted (%)   37.5   15.1   10.7   22.7  

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ENI REPORT ON THE FIRST QUARTER OF 2007

Net borrowings and leverage

Leverage is a measure of a company's level of indebtedness, calculated as the ratio between net borrowings which is calculated by excluding cash and cash equivalents and certain very liquid assets from financial debt and shareholders' equity, including minority interests. Management makes use of leverage in order to assess the soundness and efficiency of the Group balance   sheet in terms of optimal mix between net borrowings and net equity, and to carry out benchmark analysis with industry standards. In the medium term, management plans to maintain a strong financial structure targeting a level of leverage up to 0.40.

 

(million euro)

  Dec. 31, 2006   Mar. 31, 2007   Change
   
 
 
Total debt   11,699     16,470     4,771  
- Short-term debt   4,290     9,670     5,380  
- Long-term debt   7,409     6,800     (609 )
Cash and cash equivalents   (3,985 )   (6,670 )   (2,738 )
Securities not related to operations   (552 )   (270 )   282  
Non-operating financing receivables   (395 )   (5,625 )   (5,230 )
Net borrowings   6,767     3,852     (2,915 )
Shareholders' equity including minority interest   41,199     43,091     1,892  
Leverage   0.16     0.09     (0.07 )

 

Net borrowings at March 31, 2007 were euro 3,852 million, representing a decrease of euro 2,915 million from December 31, 2006 due mainly to cash inflow generated by operating activities (euro 5,563 million).
Total debt amounted to euro 16,470 million, of which euro 9,670 million were short-term (including the portion of long-term debt due within 12 months for euro 870 million) and euro 6,800 million were long-term. Short-term finance debt increased by euro 5,380 million compared with December 31, 2006. This increase was due to the need to collect the necessary funds to participate in a bid to
  purchase ex-Yukos gas assets (see “Post closing events”). Eni made recourse to undrawn borrowing facilities. These funds were placed in escrow resulting in a corresponding increase of non-operating receivables financing, with a neutral impact on net borrowings as of the end of the period.

At March 31, 2007, leverage – ratio between net borrowings and shareholders' equity – was 0.09, compared with 0.16 at December 31, 2006.

 

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ENI REPORT ON THE FIRST QUARTER OF 2007

Changes in shareholders' equity

(million euro)

       
Shareholders' equity at December 31, 2006         41,199
Net profit   2,743      
Reserve for cash flow hedges   (301 )    
Shares repurchased   (203 )    
Issue of ordinary share capital for employee share incentive schemes   8      
Dividends paid by consolidated subsidiaries to shareholders   (3 )    
Effect on equity of the shares repurchased by consolidated subsidiaries (Snam Rete Gas/Saipem)   (140 )    
Exchange differences from translation of financial statements denominated in currencies other than the euro   (223 )    
Other changes   11      
Total changes         1,892
Shareholders' equity at March 31, 2007         43,091

 

Shareholders’ equity at March 31, 2007 (euro 43,091 million) increased by euro 1,892 million from December 31, 2006, due essentially to net profit (euro 2,743 million) whose effects were offset in part by losses in cash flow   hedges taken to reserve (euro 301 million net to the related tax effect)2, the purchase of own shares and currency translation effects.

 

     
(2)   For further details see comment to net working capital.

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ENI REPORT ON THE FIRST QUARTER OF 2007

SUMMARIZED CASH FLOW STATEMENT AND CHANGE IN NET BORROWINGS

Eni's summarized group cash flow statement derives from the statutory statement of cash flows. It allows to create a link between changes in cash and cash equivalents (deriving from the statutory cash flows statement) occurred from the beginning of period to the end of period and changes in net borrowings (deriving from the summarized cash flow statement) occurred from the beginning of period to the end of period. The measure enabling to make such a link is represented by free cash flow which is the cash in excess of capital expenditure needs. Starting from free cash flow it is   possible to determine either: (i) changes in cash and cash equivalents for the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to financing activities), shareholders' equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange rate differences; (ii) changes in net borrowings for the period by adding/deducting cash flows relating to shareholders' equity and the effect of changes in consolidation and of exchange rate differences.

 

Summarized Group Cash Flow Statement (a)

Fourth Quarter

     

First Quarter

2006

 

(million euro)

 

2006

 

2007

 

% Ch.


     
 
 
1,698     Net profit       3,130     2,743     (387 )
      adjustments to reconcile to cash generated from operating profit before changes in working capital:                      
1,568     - amortization and depreciation and other non-monetary items       1,321     1,251     (70 )
(4 )   - net gains on disposal of assets       (63 )   (14 )   49  
2,314     - dividends, interest, taxes and other changes       2,843     2,397     (446 )
5,576     Cash generated from operating profit before changes in working capital       7,231     6,377     (854 )
(847 )   Changes in working capital related to operations       131     445     314  
(2,951 )   Dividends received, taxes paid, interest (paid) received       (1,499 )   (1,259 )   240  
1,778     Net cash provided by operating activities       5,863     5,563     (300 )
(2,944 )   Capital expenditure       (1,340 )   (2,013 )   (673 )
(19 )   Investments       (19 )   (10 )   9  
201     Disposals       85     12     (73 )
407     Other cash flow related to capital expenditure, investments and disposals       (108 )   (152 )   (44 )
(577 )   Free cash flow       4,481     3,400     (1,081 )
                             
(247 )   Borrowings (repayment) of debt related to financing activities       380     (5,035 )   (5,415 )
839     Changes in short and long-term financial debt       (1,851 )   4,887     6,738  
(2,412 )   Dividends paid and changes in minority interests and reserves       (356 )   (445 )   (89 )
(77 )   Effect of changes in consolidation and exchange differences       (30 )   (69 )   (39 )
(2,474 )   NET CASH FLOW FOR THE PERIOD       2,624     2,738     114  

Change in net borrowings

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
(577 )   Free cash flow       4,481     3,400     (1,081 )
      Net borrowings of acquired companies                      
      Net borrowings of divested companies       46           (46 )
72     Exchange differences on net borrowings and other changes       13     (40 )   (53 )
(2,412 )   Dividends paid and changes in minority interests and reserves       (356 )   (445 )   (89 )
(2,917 )   CHANGE IN NET BORROWINGS       4,184     2,915     (1,269 )
     
(a)   For a reconciliation with the corresponding statutory tables see Eni’s 2006 Annual Report, “Reconciliation of Cash Flows to statutory schemes” pages 79-80.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Net cash provided by operating activities came in at euro 5,563 million, allowing to cover financial requirements for capital expenditure for euro 2,013 million, the repurchase of own shares for euro 203 million by Eni SpA and for euro 242 million by Snam Rete Gas SpA and Saipem SpA, and to reduce net borrowings by euro 2,915 million.   From January 1 to March 31, 2007 a total of 8.52 million Eni shares were purchased by the company for a total cost of euro 203 million (representing an average cost of euro 23.847 per share). Since the inception of the share buy-back programme (September 1, 2000), Eni has repurchased 344 million shares, equal to 8.58% of its share capital, at a total cost of euro 5,716 million (representing an average cost of euro 16.638 per share).

CAPITAL EXPENDITURE

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,937     Exploration & Production   961     1,366     405     42.1  
453     Gas & Power   151     221     70     46.4  
272     Refining & Marketing   95     134     39     41.1  
47     Petrochemical   10     14     4     40.0  
188     Engineering & Construction   97     248     151     ..  
38     Other activities   3     14     11     ..  
48     Corporate and financial companies   23     16     (7 )   (30.4 )
(39 )   Impact of unrealized profit in inventory                        
2,944         1,340     2,013     673     50.2  

 

In the first quarter of 2007 capital expenditure amounted to euro 2,013 million, of which 85.5% related to the   Exploration & Production, Gas & Power and Refining & Marketing divisions.

 

Exploration & Production

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
139     Acquisitions of proved and unproved property       73     73     ..  
139     Italy                   ..  
      North Africa       5     5     ..  
      West Africa                   ..  
      Rest of world       68     68     ..  
                             
706     Exploration   173   373     200     ..  
38     Italy   23   34     11     47.8  
91     North Africa   48   83     25     72.9  
366     West Africa   47   68     21     44.7  
75     North Sea   15   75     60     ..  
136     Rest of world   40   113     73     ..  
                             
1,056     Development   777   909     132     17.0  
133     Italy   85   107     22     25.9  
209     North Africa   140   188     48     34.3  
294     West Africa   138   266     128     92.8  
121     North Sea   94   89     (5 )   (5.3 )
299     Rest of world   320   259     (61 )   (19.1 )
36     Other   11   11           ..  
1,937         961   1,366     405     42.1  

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ENI REPORT ON THE FIRST QUARTER OF 2007

Capital expenditure of the Exploration & Production segment (euro 1,366 million) concerned essentially development directed mainly outside Italy, in particular Kazakhstan, Egypt, Angola and Congo. Development expenditure in Italy concerned in particular the continuation of work for well drilling, plant and infrastructure in Val d’Agri and sidetrack and infilling work in mature areas. About 91% of exploration expenditure was directed outside Italy in particular Norway, Nigeria, Egypt, the United States and Indonesia. In Italy essentially the offshore   of Sicily. Acquisition of proved and unproved property essentially concerned the 70% of total expenditure for the Nikaitchuq oilfield in Alaska, in which Eni reached the 100% ownership.
As compared to the first quarter of 2006, capital expenditure increased by euro 405 million, up 42.1%, due in particular to the increase in development expenditure in Congo, Egypt and Angola, the increase in exploration expenditure in Norway, Indonesia, the United States and Nigeria, and the acquisition of reserves.

Gas & Power

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
397     Italy   140   154     14     10.0  
56     Outside Italy   11   67     56     ..  
453         151   221     70     46.4  
22     Market   7   5     (2 )   (28.6 )
      Italy                   ..  
22     Outside Italy   7   5     (2 )   (28.6 )
54     Distribution   27   25     (2 )   (7.4 )
287     Transport   91   144     53     58.2  
253     Italy   87   82     (5 )   (5.7 )
34     Outside Italy   4   62     58     ..  
90     Power generation   26   47     21     80.8  
453         151   221     70     46.4  

 

Capital expenditure in the Gas & Power segment totalled euro 221 million and related essentially to: (i) development and maintenance of Eni’s primary transmission network in Italy (euro 82 million); (ii) the import pipeline upgrade (euro 62 million); (iii) the continuation of the construction of combined cycle power plants (euro 47 million) in particular at Ferrara; (iv) development and maintenance of Eni’s natural gas distribution network in Italy (euro 25 million).   The euro 70 million increase from the first quarter of 2006 (up 46.4%) was due essentially to the import pipeline upgrade.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Refining & Marketing

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
241     Italy   79   123     44     55.7  
31     Outside Italy   16   11     (5 )   (31.3 )
272         95   134     39     41.1  
139     Refining, Supply and Logistics   67   104           55.2  
139     Italy   67   104     37     55.2  
90     Marketing   25   30     5     20.0  
59     Italy   9   19     10     ..  
31     Outside Italy   16   11     (5 )   (31.3 )
43     Other activities   3         (3 )   ..  
272         95   134     39     41.1  

 

Capital expenditure in the Refining & Marketing segment amounted to euro 134 million and concerned: (i) refining, supply and logistics in Italy (euro 104 million), in particular actions for improving flexibility and yields of refineries, among which the construction of a new hydrocracking unit at the Sannazzaro refinery; (ii) the upgrade of the distribution network in Italy (euro 19 million); (iii) the upgrade of the refined product distribution network and the purchase of service stations in the rest of Europe (euro 11 million).   Engineering & Construction
Capital expenditure in the Engineering & Construction segment amounted to euro 248 million and concerned: (i) conversion of two tanker ships into FPSO vessels that will operate in Brazil on the Golfinho 2 field and in Angola; (ii) startup of construction of a new rig and a new pipelayer.

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ENI REPORT ON THE FIRST QUARTER OF 2007

POST CLOSING EVENTS

Upstream asset acquisition in the Gulf of Mexico
On April 30, 2007 Eni agreed to acquire the Gulf of Mexico upstream activity of Dominion, one of the major American energy companies, listed on the New York Stock Exchange at the agreed price equal to US $4,757 million inclusive of exploration assets for US $680 million.
The transaction includes production, development and exploration assets located in deepwater Gulf of Mexico. The acquisition will increase Eni’s equity production in the Gulf of Mexico from the current 36 kboepd to more than 110 kboepd in the second half of 2007 and the proved and probable equity reserves by 222 million boe, at an implied cost per barrel of US $18.40. In the 2007-2010 period, production from the acquired assets is expected to average more than 75 kboepd.
In addition, Eni will further enhance its portfolio in the Gulf of Mexico thanks to new leases with significant exploration potential; approximately 60% of these leases are operated.
The transaction is subject to government approvals, 30 days notice to holders of certain preferential rights to purchase (which apply to less than 5% of total reserves), and to other customary conditions precedent. Closing is expected on July 2, 2007.

Yukos assets acquisition
On April 4, 2007 Eni, through the partnership in EniNeftegaz (60% Eni, 40% Enel SpA) acquired Lot 2 in the Yukos liquidation procedure for a total price of $5.83 billion. Lot 2 includes: 100% of OAO Arctic Gas Company, 100% of ZAO Urengoil Inc and 100% of OAO Neftegaztechnologia.
These three companies own 5 gas and condensate fields and parts of other fields in the Yamal Nenets (YNAO) region, the world’s largest gas producing region. Together they have large oil and gas reserves.
  Eni and Enel have offered Gazprom an option to acquire a 51% interest in these assets within two years. In the event that Gazprom exercises its call option, the assets will be operated through a joint venture between Eni and Gazprom which will have access to Eni’s most advanced technologies.
Lot 2 includes also various minor assets that will be sold or liquidated and 20% of OAO Gazprom Neft which will be wholly owned by Eni.
Eni offered Gazprom an option to acquire a 20% interest in OAO Gazprom Neft within two years, at a total price of $3.7 billion, in addition to financial expenses related to the acquisition. These agreements are an additional step in implementing the strategic Partnership between Eni and Gazprom signed in November 2006, under which the two companies established an alliance to develop upstream, midstream and downstream energy projects inside and outside of Russia.

Acquisition of the retail station network in the Czech Republic, Slovakia and Hungary
On April 27, 2007 Eni and ExxonMobil Central Europe Holding GmbH signed an agreement for the sale of shares of Esso spol sro (Esso Czechia), Esso Slovensko spol sro (Esso Slovakia) and ExxonMobil Hungary Kft to Eni. The agreement, subject to the approval of the relevant authorities, includes ExxonMobil's retail station network in the three countries, totaling 102 stations and its aviation business at the Prague and Bratislava airports. Additionally, the lubricants business conducted in these countries by ExxonMobil Petroleum and Chemical, is included in the transaction.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Acquisition of 70% and of the operatorship of the Nikaitchuq Field in Alaska
On April 11, 2007 Eni acquired 70% and the operatorship of the Nikaitchuq field, located on-offshore in the North Slope of Alaska. Eni, which already owned a 30% stake in the field, now retains the 100% working interest. Eni acquired the additional interest and operatorship as the result of an agreement with Kerr-McGee Oil and Gas Corporation, a wholly-owned subsidiary of Anadarko Petroleum Corporation. Nikaitchuq would be the first development project operated by Eni in Alaska. Successful appraisal drilling has been completed, confirming the potential viability of the development project. Plans for a phased development are currently being evaluated with the target of sanctioning the project by year end, and first oil to flow by the end of 2009. The Nikaitchuq project comprises the drilling of approximately 80 wells, out of which 32 are located onshore and the remaining from an offshore artificial island. All wells will then be tied back to a production facility located at Oliktok Point to reach a production of 40 kboe/d. Total investment will amount to approximately $900 million.
  Memorandum of Understanding for the acquisition of an interest in Angola LNG Ltd
On April 2, 2007 Eni and Sonangol signed a Memorandum of Understanding for the acquisition of a 13.6% stake in Angola LNG Limited Consortium (A-LNG). This company is responsible for the construction of an LNG plant in Soyo, 300 km North Luanda, with a yearly capacity of 5 mmtonnes. Upon completion of this agreement, Angola LNG Limited’s shareholding structure will be as follows: Sonangol 22.8%, Chevron 36.4%, Eni 13.6%, Total 13.6% and BP 13.6%. The project, for a total investment of approximately $4 billion, has been approved by the Angolan Government and Parliament. It envisages, for 28 years, the development of 220 bcm of gas, the production of 128 mmtonnes of LNG, 104 mmbbl of condensate and 257 mmbbl of LPG. The LNG will be directed to the United States market and will be delivered to the re-gasification plant of Pascagoula, in the Gulf of Mexico, in which Eni, following this agreement, will acquire re-gasification capacity of 5 bcm/y.

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ENI REPORT ON THE FIRST QUARTER OF 2007

OUTLOOK FOR 2007

The outlook for Eni in 2007 remains positive, with key business trends for the year as follows:
  • Production of liquids and natural gas is forecast to remain at the same level as 2006 (in 2006 oil and gas production averaged 1.77 mmboe/d). Additional production expected in the second half of the year from acquired properties in the Gulf of Mexico and Congo, and the expected build-up in gas production in Libya will enable Eni to recover the first quarter decline in production due to escalating social unrest in Nigeria and the loss of the Dación oilfield in Venezuela;
  • Sales volumes of natural gas worldwide are expected to increase by 1% over 2006 (actual sales volumes in 2006 were 97.48 bcm). Major increases are expected in certain target markets in the Rest of Europe, mainly in the Iberian Peninsula, the North of Europe, France and Germany/Austria markets;
  • Sales volumes of electricity are expected to slightly increase from 2006 (actual volumes in 2006 were 31.03 TWh);
  • Refining throughputs on Eni’s account are forecast to slightly decrease from 2006 (actual throughputs in 2006 were 38.04 mmtonnes) due to the expiration of a processing contract at the Priolo refinery owned by a third party late in 2006, to be offset by higher throughputs expected at the Gela, Livorno and Taranto refineries;
  • Retail sales of refined products are expected to slightly increase from 2006 (actual volumes sold in 2006 were 12.48 mmtonnes). Increases are expected on both the Italian and European markets due to the entry into service of new outlets, following also the acquisition of service stations in target markets.
  In 2007 management expects Eni’s capital expenditure on exploration and capital projects to amount to approximately euro 10.5 billion, representing a 34% increase over 2006. Approximately 86% of this capital expenditure programme is expected to be deployed in the Exploration & Production, Gas & Power and Refining & Marketing divisions. Furthermore, acquisitions of assets and interests amounting to euro 9.2 billion are forecast in the year, mainly related to: (i) the already closed transaction for the purchase of ex-Yukos assets; (ii) the other transactions whose closing is foreseen by the end of the year, including the purchase of upstream assets in the Gulf of Mexico and Congo, and a retail station network in the Central-Eastern Europe. Assuming Gazprom exercises its call options to purchase a 20% interest in OAO Gazprom Neft and a 51% interest in ex-Yukos gas assets from Eni, net cash outflows used in investing activities will decrease to euro 16.2 billion.
On the basis of the expected cash outflows for this capital expenditure and acquisition program, and shareholders remuneration, also assuming a $55/barrel scenario for the Brent crude oil, Eni foresees a leverage ranging from 0.3 to 0.4 by the end of the year, depending on the exercise of the above mentioned call options by Gazprom.

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ENI REPORT ON THE FIRST QUARTER OF 2007

OPERATING RESULTS BY DIVISION

Exploration & Production

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
6,152     Net sales from operations       7,412     6,361     (1,051 )   (14.2 )
3,141     Operating profit       4,308     3,132     (1,176 )   (27.3 )
54     Exclusion of special items:       (57 )         57        
51     - asset impairments                            
(7 )   - gains on disposal of assets       (57 )         57        
10     - provision for redundancy incentives                            
3,195     Adjusted operating profit       4,251     3,132     (1,119 )   (26.3 )
(22 )   Net financial incomes (expenses) (a)       (17 )   (35 )   (18 )      
(18)     Net income (expenses) from investments (a)       10     10              
(1,851 )   Income taxes (a)       (2,149 )   (1,698 )   451        
58.7     Tax rate   (%)   50.6     54.7     4.1        
1,304     Adjusted net profit       2,095     1,409     (686 )   (32.7 )
      Results also include:                            
1,418     - amortizations and depreciations       1,095     1,240     145     13.2  
419     - of which amortizations of exploration expenditure       187     375     188     ..  
1,937     Capital expenditure       961     1,366     404     42.1  
      Production (b)                            
1,079     Liquids (c)   (kbbl/d)   1,143     1,030     (113 )   (9.9 )
4,132     Natural gas   (mmcf/d)   3,920     4,061     141     3.6  
1,796     Total hydrocarbons   (kboe/d)   1,827     1,734     (93 )   (5.1 )
      Average realizations                            
54.85     Liquids (c)   ($/bbl)   56.27     54.39     (1.88 )   (3.3 )
5.39     Natural gas   ($/mmcf)   5.23     2.30     0.07     1.3  
45.53     Total hydrocarbons   ($/boe)   46.71     45.12     (1.59 )   (3.40 )
      Average oil market prices                            
59.68     Brent dated   ($/bbl)   61.75     57.75     (4.00 )   (6.5 )
46.26     Brent dated   (euro/bbl)   51.37     44.08     (7.29 )   (14.2 )
59.94     West Texas Intermediate   ($/bbl)   63.29     57.99     (5.30 )   (8.4 )
235.20     Gas Henry Hub   ($/kmc)   271.90     266.60     (5.30 )   (1.9 )
     
(a)   Excluding special items.
(b)   Includes Eni's share of production of equity-accounted entities.
(c)   Includes condensates.

 

Results
Adjusted operating profit for the first quarter of 2007 was euro 3,132 million, a decrease of euro 1,119 million from the first quarter 2006, or 26.3%, due primarily to: (i) the adverse impact of approximately euro 300 million resulting from the appreciation of the euro versus the dollar; (ii) lower production sold, down 9.5 mmboe; (iii) lower oil realizations in dollars (down 3.3%), partly offset by higher gas prices (up 1.3%); (iv) higher expenses incurred
  in connection with exploratory activity (euro 188 million; euro 218 on a constant exchange rate basis); (v) higher production costs and amortization/depreciation charges, reflecting also the impact of sector-specific inflation.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Production

Daily production of hydrocarbons by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,796     Daily production of oil and natural gas (a)   (kboe/d)   1,827     1,734     (93 )   (5.1 )
232     Italy       247     223     (24 )   (9.7 )
571     North Africa       541     566     25     4.6  
372     West Africa       382     337     (45 )   (11.8 )
291     North Sea       298     287     (11 )   (3.7 )
330     Rest of World       359     321     (38 )   (10.6 )
159.2     Oil and natural gas production sold (a)   (mmboe)   159.5     150.1     (9.4 )   (5.9 )

Daily production of liquids by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,079     Production of liquids (a)   (kbbl/d)   1,143     1,030     (113 )   (9.9 )
80     Italy       82     77     (5 )   (6.1 )
334     North Africa       325     328     3     0.9  
315     West Africa       339     288     (51 )   (15.0 )
181     North Sea       188     170     (18 )   (9.6 )
169     Rest of World       209     167     (42 )   (20.1 )

Daily production of natural gas by region

Fourth Quarter

     

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
4,132     Production of natural gas (a)   (mmcf/d)   3,920     4,061     141     3.6  
883     Italy       954     848     (106 )   (11.1 )
1,377     North Africa       1,236     1,377     141     11.4  
318     West Africa       247     283     36     14.6  
636     North Sea       636     671     35     5.5  
918     Rest of World       847     882     35     4.1  
     
(a)   Includes Eni's share of production of equity-accounted entities.

 

Oil and natural gas production in the first quarter 2007 averaged 1,734 kboe/d, a decrease of 93 kboe/d from the same period of the previous year (down 5.1%). This reduction was due primarily to the unilateral cancellation of the Dación field service contract by the Venezuelan state company PDVSA with effect from April 1, 2006 (down 60 kboe/d) and social unrest in Nigeria. Factoring in these effects, oil and natural gas production level was in line with the first quarter 2006. Production increases were achieved mainly in Libya, Kazakhstan and   the Gulf of Mexico offsetting mature field declines mainly in Italy and facility shutdown.

Daily production of oil and condensates (1,030 kbbl) decreased by 113 kbbl, or 9.9% from the first quarter of 2006. Production decreases were reported mainly in Venezuela and Nigeria due to the above mentioned causes and in the United Kingdom due to a technical problem occurred in the Elgin/Franklin field (Eni’s interest 21.87%) and ordinary maintenance shutdowns at other

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ENI REPORT ON THE FIRST QUARTER OF 2007

facilities. In Italy a few technical problems occurred at the FPSO operating the Aquila field. Main increases were registered in Kazakhstan due to maintenance actions on facilities performed in the first quarter of 2006, and the United States due to the resumption of full activity at plants damaged by hurricanes in the second half of 2005.   Daily production of natural gas for the first quarter (4,061 mmcf/d) increased by 141 mmcf, or 3.6% mainly as a result of the build-up of the Bahr Essalam field offshore Libya, full operations at the fifth train of the Bonny LNG plant in Nigeria, a better performance of Norway’s largest fields, and full production of Bayu Undan gas field offshore Australia. Gas production in Italy decreased due to mature field declines.

Gas & Power

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
8,170     Net sales from operations   9,134     8,543     (591 )   (6.5 )
1,303     Operating profit   1,199     1,641     442     36.9  
(41 )   Exclusion of inventory holding (gains) losses   (30 )   40     70        
7     Exclusion of special items:   34     2     (32 )      
      of which:                        
      Non-recurring items                        
7     Other special items   34     2     (32 )      
2     - environmental provision   20           (20 )      
15     - provisions for redundancy incentives   14     2     (12 )      
(10 )   - other                        
1,269     Adjusted operating profit   1,203     1,683     480     39.9  
832     Market and Distribution   705     1,177     472     67.0  
286     Transport in Italy   305     286     (19 )   (6.2 )
144     Transport outside Italy   154     163     9     5.8  
7     Power generation (a)   39     57     18     46.2  
                               
(1 )   Net financial incomes (expenses) (b)   6     3     (3 )      
97     Net income (expenses) from investments (b)   137     115     (22 )      
(492 )   Income taxes (b)   (467 )   (642 )   (175 )      
36.0     Tax rate (%)   34.7     35.6     0.9        
873     Adjusted net profit   879     1,159     280     31.9  
453     Capital expenditure   151     221     70     46.4  
     
(a)   Starting on January 1, 2007, results from marketing of electricity have been included in results from market and distribution activities following an internal reorganization. As a consequence of this, electricity generation activity conducted by EniPower subsidiary comprises only results from production of electricity. Prior quarter results have not been restated.
(b)   Excluding special items.

 

Results
The adjusted operating profit of the Gas & Power division totalled euro 1,683 million, up euro 480 million or 39.9% from the first quarter of 2006, reflecting primarily: (i) increased natural gas selling margins mainly owing to a favorable trading environment reflecting in particular the effect of the euro/dollar exchange rate; (ii) a favorable evolution of the regulatory framework in Italy. This reflected the enactment of Resolution No. 79/2007 by the Authority for Electricity and Gas implementing a new setup of the indexation mechanism of the raw material cost component in supplies to residential and commercial
  users related to the period from January 1, 2005 to June 30, 2006. Following this, Eni has partially or totally reversed provisions accrued in the accounts for 2005 and the first half of 2006; (iii) the fact that higher purchase costs were incurred in the first quarter of 2006, owing to a climatic emergency for the winter time 2005-2006.
These positives were partly offset by a decline in natural gas sales of affiliates (down 2.87 bcm, or 10.4%) due to lower European gas demand as a consequence of the unusually mild weather conditions of the first quarter of 2007, partly offset by a growth in sales in certain target

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ENI REPORT ON THE FIRST QUARTER OF 2007

markets in the Rest of Europe. Lower gas demand negatively affected the operating performance of transport activities in Italy and volumes distributed on low pressure networks. Sales volumes of electricity decreased by 0.12 TWh, or 1.6%.

Special charges for the quarter referred to redundancy incentives (euro 2 million).
  The adjusted net profit was euro 1,159 million up euro 280 million, or 31.9%, reflecting the increased adjusted operating profit, offset in part lower results reported by certain affiliates engaged in natural gas distribution in Italy, due to mild weather conditions.

Sales

Fourth Quarter

 

(bcm)

 

First Quarter

2006

  Natural gas sales  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
14.09     Italy to third parties (*)       17.47     15.41     (2.06 )   (11.8 )
3.45     Wholesalers (selling companies)       5.06     4.62     (0.44 )   (8.7 )
0.56     Gas release       0.59     0.49     (0.10 )   (16.9 )
10.08     End Customers       11.82     10.30     (1.52 )   (12.9 )
3.50          Industries       3.80     3.33     (0.47 )   (12.4 )
4.30          Power generation       4.27     3.93     (0.34 )   (8.0 )
2.28          Residential       3.75     3.04     (0.71 )   (18.9 )
1.55     Own consumption (*)       1.47     1.39     (0.08 )   (5.4 )
8.14     Rest of Europe (*)       8.57     7.90     (0.67 )   (7.8 )
0.12     Outside Europe       0.16     0.10     (0.06 )   (37.5 )
23.90     Total sales to third parties and own consumption       27.67     24.80     (2.87 )   (10.4 )
1.97     Sales of natural gas of Eni's affiliates (net to Eni)       2.41     2.27     (0.14 )   (5.8 )
0.01          Italy (*)       0.01     0.01              
1.83          Rest of Europe (*)       2.33     2.10     (0.23 )   (9.9 )
0.13          Outside Europe       0.07     0.16     0.09 )   128.6  
25.87     Total sales and own consumption (G&P)       30.08     27.07     (3.01 )   (10.0 )
1.06     Upstream in Europe       1.12     1.07     (0.05 )   (4.5 )
26.93     Worldwide gas sales       31.20     28.14     (3.06 )   (9.8 )
                                   
26.68     Gas sales in Europe       30.97     27.88     (3.09 )   (10.0 )
25.62     G&P in Europe (*)       29.85     26.81     (3.04 )   (10.2 )
1.06     Upstream in Europe       1.12     1.07     (0.05 )   (4.5 )
                                   
22.45     Gas volumes transported in Italy   (bcm)   24.89     23.51     (1.38 )   (5.5 )
14.97     Eni       8.77     15.55     6.78     77.3  
7.48     On behalf of third parties       16.12     7.96     (8.16 )   (50.6 )
                                   
7.79     Electricity sold   (TWh)   7.73     7.61     (0.12 )   (1.6 )
     
(*)   Market segments with asterisk merge into "G&P in Europe".

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ENI REPORT ON THE FIRST QUARTER OF 2007

Natural gas sales for the first quarter of 2007 amounted to 28.14 bcm, including own consumption and sales by affiliates and upstream sales in Europe, with a decrease of 3.06 bcm from the first quarter of 2006, or 9.8%. This decline was impacted by lower seasonal gas sales due to an unusually mild winter.

In an increasingly competitive market, sales in the Italian market were 15.41 bcm with a decrease of 2.06 bcm, or 11.8%. All market segments posted sale volumes declines from the first quarter of 2006: sales to residential users were down by 0.71 bcm; sales to industrial users were down by 0.47 bcm; sales to wholesalers were down by 0.44 bcm; sales to power generation were down by 0.34 bcm. Sales under the gas release1 program (0.49 bcm) declined by 0.1 bcm. Own consumption (1.38 bcm) declined by 0.08 bcm due to lower supplies to EniPower.

Gas sales in the Rest of Europe were 7.9 bcm with a decrease of 0.67 bcm, or 7.8%, due to: (i) lower sales under long-term supply contracts to Italian importers (down 0.75 bcm), despite the full production of natural gas from the Libyan fields; (ii) lower sales in the Hungarian market (down 0.49 bcm). These decreases were partly offset by increases in the supplies to the Turkish (up 0.34 bcm) and Spanish (up 0.18 bcm) markets.
  Sales of subsidiaries outside Europe (0.1 bcm) declined by 0.06 bcm due to lower supplies to the Argentinean market.

Natural gas sales of Eni’s affiliates in the rest of Europe (net to Eni and net of Eni’s supplies) amounted to 2.1 bcm, a 0.23 bcm decline related in particular to: (i) GVS (Eni’s interest 50%) with 0.93 bcm; (ii) Unión Fenosa Gas (Eni’s interest 50%) with 0.57 bcm.

Natural gas sales of Eni’s affiliates outside Europe (net to Eni and net of Eni’s supplies) amounted to 0.16 bcm, a 0.23 bcm decline related in particular to Unión Fenosa Gas (Eni’s interest 50%) with 0.13 bcm.

Eni transported 23.51 bcm of natural gas in Italy, a decrease of 1.38 bcm from the first quarter of 2006, down 5.5%, due to a decline in domestic demand. Volumes transported on behalf of third parties declined by 0.81 bcm, those transported on behalf of Eni declined by 0.57 bcm.

Sales of electricity (7.61 TWh) declined by 0.12 TWh, or 1.6%.

 

 

 

     
(1)   In June 2004 Eni agreed with the Antitrust Authority to sell a total volume of 9.2 billion cubic meters of natural gas (2.3 billion cubic meters/year) in the four thermal years from October 1, 2004 to September 30, 2008 at the Tarvisio entry point into the Italian network.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Resolution No. 79/2007 of the Authority for Electricity and Gas “Revision of the economic conditions of supplies in the January 1, 2005 to March 31, 2007 period and criteria for their updating”.

Following the cancellation of Resolution No. 248/2004 by the Council of State for formal flaws, on March 29, 2007 the Authority for Electricity and Gas published Resolution No. 79/2007 after concluding a consultation procedure with gas operators. This Resolution organizes in a single document all the changes applied to the determination and updating of economic conditions for natural gas supplies. In particular with this Resolution the Authority: (i) confirmed the indexation mechanism for the raw material cost component contained in Resolution No. 248/2004 and the changes introduced to this mechanism by Resolution No. 134/06 starting on July 1, 2006; (ii) waiving this provision, it reviewed the updating of the raw material cost component for 2005 reaching incremental values equal to those deriving
  from the application of the indexation criteria of Resolution No. 195/02; this cancels the negative impact of Resolution No. 248/2004 on Eni’s 2005 accounts; (iii) decided that selling companies, only for wholesale purchase/sale contracts entered after January 1, 2005 and valid in the January 1, 2006-June 30, 2006 period, offer their customers new contractual conditions consistent with the new indexation mechanism before June 4, 20072 , and inform the Authority, before June 29, 20072, together with their wholesaler that they have complied with this requirement. Selling companies complying with this requirement will be entitled to 50% of the difference between the updating of the raw material cost component under the new mechanism and the more favorable one under Resolution No. 195/2002 applied to volumes consumed by customers under the 200 kcm threshold. This Resolution determined the total or partial redundancy of liabilities accrued in Eni’s accounts for 2005 and 2006 that have been consequently reversed.

 

 

     
(2)   Dates changes by Resolution No. 101/2007 of the Authority for Electricity and Gas.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Refining & Marketing

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
8,579     Net sales from operations       9,280     7,943     (1,337 )   (14.4 )
(386 )   Operating profit       89     (10 )   (99 )   ..  
386     Exclusion of inventory holding (gains) losses       (47 )   112     159        
148     Exclusion of special items:       47     18     (29 )      
      of which:                            
109     Non-recurring items                            
39     Other special items       47     18     (29 )      
13     - asset impairments                            
27     - environmental provisions       44     17     (27 )      
30     - provisions for redundancy incentives       5     1     (4 )      
4     - provision to the reserve for contingencies       1           (1 )      
(35 )   - other       (3 )         3        
148     Adjusted operating profit       89     120     31     34.8  
31     Net income (expenses) from investments (a)       47     51     4     8.5  
(64 )   Income taxes (a)       (50 )   (58 )   (8 )   16.0  
35.8     Tax rate (%)       36.8     33.9     (2.9 )      
115     Adjusted net profit       86     113     27     31.4  
272     Capital expenditure       95     134     39     41.1  
                                   
      Global indicator refining margin                            
2.18     Brent   ($/bbl)   2.95     3.06     0.11     3.7  
1.69     Brent   (euro/bbl)   2.45     2.34     (0.11 )   (4.5 )
4.87     Ural   ($/bbl)   5.76     6.07     0.31     5.4  
     
(a)   Excluding special items.

 

Results
The Refining & Marketing division reported an adjusted operating profit of euro 120 million, representing an increase of euro 31 million from the first quarter of 2006, or 34.8%. This increase reflected primarily a better operating performance delivered by the refining activity, which was boosted by higher processed volumes and better yields also in light of lower maintenance shutdowns. The benefit of higher refining margins (margins on Brent crude oil were up 0.11 dollar/bbl, or 3.7%) was more than offset by the negative impact of the euro appreciation over the dollar. Marketing activities in Italy reported a lower operating profit due
  mainly to lower retail margins and a decline in wholesale volumes as a consequence of lower heating oil demand in Italy, in particular from the power generation sector caused by an unusually mild winter.

The adjusted net profit was euro 113 million, up euro 27 million, or 31.4%, due to the improved operating performance.

Special charges excluded from the adjusted operating profit for the first quarter of 2007 were euro 18 million, reflecting environmental provisions and provisions for redundancy incentives.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Throughputs and sales

Fourth Quarter

 

(mmtonnes)

 

First Quarter

2006

  Refining throughputs and sales  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
9.05     Refining throughputs on own account Italy       7.49     7.86     0.37     4.9  
1.20     Refining throughputs on own account rest of Europe       1.12     1.14     0.02     1.8  
7.36     Refining throughputs of wholly-owned refineries       5.86     6.67     0.81     13.8  
100     Utilization rate of balanced capacity   (%)   100     100              
2.16     Retail sales Italy       2.06     1.98     (0.08 )   (3.9 )
0.97     Retail sales rest of Europe       0.87     0.90     0.03     3.4  
3.13     Sub-total retail sales       2.93     2.88     (0.05 )   (1.7 )
2.93     Wholesale Italy       2.94     2.61     (0.33 )   (11.2 )
1.06     Wholesale rest of Europe       1.03     1.05     0.02     1.9  
0.10     Wholesale rest of World       0.10     0.13     0.03     30.0  
5.96     Other sales       5.32     5.67     0.35     6.6  
13.18     Sales       12.32     12.34     0.02     0.2  
                                   
      Refined product sales by region   (mmtonnes)                        
7.71     Italy       7.55     7.30     (0.25 )   (3.3 )
2.03     Rest of Europe       1.90     1.95     0.05     2.6  
3.44     Rest of World       2.87     3.09     0.22     7.7  

 

Refining throughputs on Eni’s own account increased by 390 ktonnes from the first quarter of 2006, to 9 mmtonnes, or 4.5%. This increase was due to higher volumes processed at the in Livorno and Venice refineries also reflecting lower maintenance shutdowns, partly offset by the expiration of a processing contract at the Priolo refinery owned by a third party and lower throughputs at the Gela and Taranto refineries due to planned maintenance shutdowns.

The wholly-owned refineries throughputs increased by 0.81 mmtonnes from the first quarter of 2006, to 6.67 mmtonnes, or 13.8%, mainly in the Livorno, Taranto and Porto Marghera refineries. The wholly-owned refinery utilization rate was 100% based on utilization rates of refinery balanced capacity.

Sales of refined products increased by 20 ktonnes from the first quarter of 2006, to 12.34 mmtonnes, or 0.2%, due to: (i) higher volumes sold to oil companies and traders in Italy, partly offset by lower volumes sold to the petrochemical sector reflecting the expiration of a processing contract at the Priolo refinery (overall up 350 ktonnes); and (ii) higher sales on both the retail and wholesale markets in the Rest of Europe (up 50 ktonnes). These positives were partly offset by a decline in both the retail and wholesale markets in Italy (down 410 ktonnes) due to the impact of mild weather in the first quarter 2007 and competitive pressure.
  Sales of refined products on the retail market in Italy decreased by 80 ktonnes from the first quarter of 2006, to 1.98 mmtonnes, or 3.9%, primarily due to competitive pressure and lower demand. Retail market share in Italy declined by 1 percentage point from 29.3% in the first quarter of 2006 to 28.3%. Average throughput (0.56 mmliters in the first quarter of 2007) declined by approximately 20 kliters from the same period in 2006.
Sales on the retail market in the Rest of Europe increased by 30 ktonnes from the first quarter of 2006, to 0.9 mmtonnes, or 3.4%, mainly in Spain. Market share outside Italy grew slightly from 3.1% in the first quarter of 2006 to 3.2% in the first quarter of 2007. Average throughput (0.58 mmliters in the first quarter of 2007) increased by approximately 20 kliters from the same period in 2006.

Sales on wholesale markets in Italy decreased by 330 ktonnes from the first quarter of 2006, to 2.61 mmtonnes, due to lower demand for heating products in particular from the power generation sector caused by unusually milder weather.
Sales on wholesale markets in the Rest of Europe increased by 20 ktonnes, to 1.05 mmtonnes, primarily reflecting the increase in sales in the Czech Republic.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Petrochemicals

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,740     Net sales from operations       1,728     1,674     (54 )   (3.1 )
72     Operating profit       39     115     76     ..  
(4 )   Exclusion of inventory holding (gains) losses       (17 )   3     20        
86     Exclusion of special items:       1     4     3        
      of which:                            
13     Non-recurring items                            
73     Other special items       1     4     3        
50     - asset impairments                            
14     - provisions for redundancy incentives             4     4        
11     - provision to the reserve for contingencies       2           (2 )      
(2 )   - other       (1 )         1        
154     Adjusted operating profit       23     122     99     ..  
1     Net income (expenses) from investments (a)                            
(14 )   Income taxes (a)       (7 )   (43 )   (36 )      
141     Adjusted net profit       16     79     63     ..  
47     Capital expenditure       10     14     4     40.0  

 

Results
Adjusted operating profit in the first quarter of 2007 amounted to euro 122 million increasing by euro 99 million from the first quarter of 2006 due mainly to higher selling margins, essentially the cracker margin and to a lower extent the aromatics business.
  Special charges in the first quarter concerned essentially redundancy incentives.

Production and sales

Fourth Quarter

 

(ktonnes)

 

First Quarter

2006

     

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,789     Production       1,915     2,227     312     16.3  
1,323     Sales of petrochemical products       1,411     1,417     6     0.4  
781     Basic petrochemicals       758     771     13     1.7  
226     Styrene and elastomers       261     272     11     4.2  
316     Polyethylene       392     374     (18 )   (4.6 )

 

Sales of petrochemical products (1,417 ktonnes) were stable from the first quarter of 2006, due essentially to higher sales of (i) olefins (up 8.1%) due to higher availability of ethylene (up 15.2%) and polypropylene (up 5.5%) due to the purchase by Syndial of the Porto Torres plant; (ii) styrene (up 4.7%) due to a positive demand, in particular for ABS/SAN (up 100%). Declines concerned: (i) intermediates (down 8.4%) due to lower product availability, in particular cycloexanone (down 17.5%) and acetone (down 11.9%); (ii) aromatics (down 4.8%) related in particular to xylene (down 13.3%), due to a different setup of the Priolo plant   following the accident occurred in the nearby refinery in the second quarter of 2006; (iii) polyethylene (down 4.6%) due to lower LDPE (down 7.3%) and LLDPE (down 6.3%) sales due to an unusually high demand in the first months of 2006 resulting from the build-up of inventories.
Petrochemical production (2,227 ktonnes) increased by 312 ktonnes from the first quarter of 2006, up 16.3% due to the consolidation of operations at Porto Torres (up 282 ktonnes). Excluding this effect production increased by 30 ktonnes (up 2%) due in particular to the growth registered at the Sarroch, Ravenna and Brindisi plants.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Engineering & Construction

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
1,969     Net sales from operations       1,310     1,962     652     49.8  
149     Operating profit       78     176     98     ..  
3     Exclusion of special items:                            
1     - asset impairments                            
2     - provisions for redundancy incentives                            
152     Adjusted operating profit       78     176     98     ..  
47     Net income (expenses) from investments (a)       41     26     (15 )      
(68 )   Income taxes (a)       (32 )   (57 )   (25 )      
131     Adjusted net profit       87     145     58     66.7  
188     Capital expenditure       97     248     151     ..  
     
(a)   Excluding special items.

 

Results
Adjusted operating profit for the first quarter of 2007 was euro 176 million, up euro 98 million from the first quarter of 2006 due to a better operating performance in all business areas, in particular in the Offshore and Onshore construction areas due to higher activity levels and margins.
  Exploration & Production, Gas & Power and Refining & Marketing divisions.

 

Orders

(million euro)

 

First Quarter

   
   

2006

 

2007

 

Change

 

% Ch.

   
 
 
 
Orders acquired   1,310     2,368     1,058     80.8  
Offshore construction   308     1,065     757     245.8  
Onshore construction   839     1,177     338     40.3  
Offshore drilling   105     72     (33 )   (31.4 )
Onshore drilling   58     54     (4 )   (6.9 )
of which:                        
- Eni   223     445     222     99.6  
- third parties   1,087     1,923     836     76.9  
of which:                        
- Italy   112     71     (41 )   (36.6 )
- Outside Italy   1,196     2,297     1,099     91.7  
                 
   

Dec. 31, 2006

 

Mar. 31, 2007

 

Change

 

% Ch.

   
 
 
 
Order backlog   13,191     13,268     77     0.6  
Offshore construction   4,283     4,404     121     2.8  
Onshore construction   6,285     6,284     (1 )      
Offshore drilling   2,247     2,221     (26 )   (1.2 )
Onshore drilling   376     359     (17 )   (4.5 )
of which:                        
- Eni   2,602     2,853     251     9.6  
- third parties   10,589     10,415     (174 )   (1.6 )
of which:                        
- Italy   1,280     1,168     (112 )   (8.8 )
- Outside Italy   11,911     12,100     189     1.6  

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ENI REPORT ON THE FIRST QUARTER OF 2007

Other activities

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
161     Net sales from operations       214     57     (15 )   (73.4 )
(221 )   Operating profit       (65 )   (16 )   49     75.4  
144     Exclusion of special items:       2     (34 )   (36 )      
      of which:                            
62     Non-recurring items                            
82     Other special items       2     (34 )   (36 )      
62     - environmental provisions                            
12     - asset impairments       3     3              
1     - provisions for redundancy incentives                            
7     - other       (1 )   (37 )   (36 )      
(77 )   Adjusted operating profit       (63 )   (50 )   13     20.6  
(7 )   Net financial incomes (expenses) (a)                            
(1 )   Net income (expenses) from investments (a)       5           (5 )      
(85 )   Adjusted net profit       (58 )   (50 )   8     13.8  
38     Capital expenditure       3     14     11     ..  
     
(a)   Excluding special items.

 

Adjusted net loss of euro 50 million is essentially in line with the first quarter of 2006.
Special charges excluded from net losses of euro 34 million
  related in particular to the settlement reached by Syndial and Dow Chemical on some contractual issues pending between the two companies.

Corporate and financial companies

Fourth Quarter

 

(million euro)

 

First Quarter

2006

  Results  

2006

 

2007

 

Change

 

% Ch.


     
 
 
 
345     Net sales from operations       307     282     (25 )   (8.1 )
(89 )   Operating profit       (51 )   (38 )   13     25.5  
36     Exclusion of special items:       5     3     (2 )      
29     - provisions for redundancy incentives       5     3     (2 )      
11     - environmental provisions                            
(4 )   - other                            
(53 )   Adjusted operating profit       (46 )   (35 )   11     23.9  
87     Net financial incomes (expenses) (a)       53     (101 )   (154 )      
1     Net income (expenses) from investments (a)                            
22     Income taxes (a)       (1 )   50     51        
57     Adjusted net profit       6     (86 )   (92 )   ..  
48     Capital expenditure       23     16     (7 )   (30.4 )
     
(a)   Excluding special items.

 

Adjusted net loss of euro 86 million increased by euro 92 million from the first quarter of 2006 due to losses recognized on the fair value evaluation of certain financial derivatives instruments recorded in the profit and loss account instead of being recognized in connection with related assets, liabilities and commitments   because these instruments do not meet the formal criteria to be assessed as contracts hedges under IFRS including the time value component.

This negative was partly offset by a lower operating loss (down euro 11 million).

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

Non-GAAP measures

RECONCILIATION OF REPORTED OPERATING PROFIT AND NET PROFIT TO RESULTS ON AN ADJUSTED BASIS

 

 

Management evaluates Group and business performance on the basis of adjusted operating profit and adjusted net profit, which are arrived at by excluding inventory holding gains or losses and special items. Further, finance charges on finance debt, interest income, charges or income deriving from the fair value evaluation of derivative financial instruments held for trading purposes, and exchange rate differences are excluded when determining adjusted net profit of each business segment.
The taxation effect of such items excluded from adjusted net profit is determined based on the specific rate of taxes applicable to each item, with the exception of finance charges or income, to which the Italian statutory tax rate of 33% is applied.
Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or U.S. GAAP. Management includes them to facilitate comparison of base business performance across periods and allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models. In addition, management uses segmental adjusted net profit when calculating return on average capital employed (ROACE) by each business segment.

The following is a description of items which are excluded from the calculation of adjusted results.

Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold calculated using the weighted average cost method of inventory accounting.

Special items include certain relevant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-recurring items
  under such circumstances; or (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write-ups and gains or losses on divestments even though they occurred in past periods or are likely to occur in future ones. As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non-recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. In addition, gains or losses on the fair value evaluation of derivative financial instruments held for trading purposes and exchange rate differences are excluded from the adjusted net profit of business segments.
Therefore, the adjusted net profit of business segments includes finance charges or income deriving from certain segment-operated assets, i.e., interest income on certain receivables financing and securities related to operations and finance charges pertaining to the accretion of certain provisions recorded on a discounted basis (as in the case of the asset retirement obligations in the Exploration & Production division).
Finance charges or interest income and related taxation effects excluded from the adjusted net profit of the business segments are allocated on the aggregate Corporate and financial companies.

For a reconciliation of adjusted operating profit and adjusted net profit to reported operating profit and reported net profit see tables below.

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

First Quarter 2007

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemical

 

E&C

 

Other activities

 

Corporate and financial companies

 

Impact of
unrealized profit in inventory

 

Group

   
 
 
 
 
 
 
 
 
Reported operating profit   3,132     1,641     (10 )   115     176     (16 )   (38 )   105     5,105  
Exclusion of inventory holding (gains) losses         40     112     3                             155  
Exclusion of special items:                                                      
of which:                                                      
Non-recurring (income) charges                                                      
Other special (income) charges:         2     18     4           (34 )   3           (7 )
     environmental charges               17                                   17  
     asset impairments                                 3                 3  
     provision for redundancy incentives         2     1     4                 3           10  
     other                                 (37 )               (37 )
Special items of operating profit         2     18     4           (34 )   3           (7 )
Adjusted operating profit   3,132     1,683     120     122     176     (50 )   (35 )   105     5,253  
Net financial (expense) income (*)   (35 )   3                             (101 )         (133 )
Net income from investments (*)   10     115     51           26                       202  
Income taxes (*)   (1,698 )   (642 )   (58 )   (43 )   (57 )         50     (39 )   (2,487 )
Tax rate (%)   54.7     35.6     33.9                                   46.7  
Adjusted net profit   1,409     1,159     113     79     145     (50 )   (86 )   66     2,835  
of which:                                                      
- net profit of minorities                                                   155  
- Eni's adjusted net profit                                                   2,680  
                                                       
Eni's reported net profit                                                   2,588  
Exclusion of inventory holding (gains) losses                                                   97  
Exclusion of special items                                                   (5 )
- non-recurring (income) charges                                                      
- other special (income) charges                                                   (5 )
Eni's adjusted net profit                                                   2,680  
     
(*)   Excluding special items.

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

First Quarter 2006

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemical

 

E&C

 

Other activities

 

Corporate and financial companies

 

Impact of
unrealized profit in inventory

 

Group

(million euro)  
 
 
 
 
 
 
 
 
Reported operating profit   4,308     1,199     89     39     78     (65 )   (51 )   (2 )   5,595  
Exclusion of inventory holding (gains) losses         (30 )   (47 )   (17 )                           (94 )
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges                                                      
Other special (income) charges:   (57 )   34     47     1           2     5           32  
     environmental charges         20     44                                   64  
     asset impairments                                 3                 3  
     gains on disposal of assets   (57 )                                             (57 )
     provisions to the reserve for contingencies               1     2                             3  
     provision for redundancy incentives         14     5                       5           24  
     other               (3 )   (1 )         (1 )               (5 )
Special items of operating profit   (57 )   34     47     1           2     5           32  
Adjusted operating profit   4,251     1,203     89     23     78     (63 )   (46 )   (2 )   5,533  
Net financial (expense) income (*)   (17 )   6                             53           42  
Net income from investments (*)   10     137     47           41     5                 240  
Income taxes (*)   (2,149 )   (467 )   (50 )   (7 )   (32 )         (1 )   1     (2,705 )
Tax rate (%)   50.6     34.7     36.8                                   46.5  
Adjusted net profit   2,095     879     86     16     87     (58 )   6     (1 )   3,110  
of which:                                                      
- net profit of minorities                                                   156  
- Eni's adjusted net profit                                                   2,954  
                                                       
Eni's reported net profit                                                   2,974  
Exclusion of inventory holding (gains) losses                                                   (59 )
Exclusion of special items                                                   39  
- non-recurring (income) charges                                                      
- other special (income) charges                                                   39  
Eni's adjusted net profit                                                   2,954  
     
(*)   Excluding special items.

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ENI REPORT ON THE FIRST QUARTER OF 2007

Fourth Quarter 2006

(million euro)  

E&P

 

G&P

 

R&M

 

Petrochemical

 

E&C

 

Other activities

 

Corporate and financial companies

 

Impact of
unrealized profit in inventory

 

Group

   
 
 
 
 
 
 
 
 
Reported operating profit   3,141     1,303     (386 )   72     149     (221 )   (89 )   (12 )   3,957  
Exclusion of inventory holding (gains) losses         (41 )   386     (4 )                           341  
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges               109     13           62                 184  
Other special (income) charges:   54     7     39     73     3     82     36           294  
     environmental charges         2     27                 62     11           102  
     asset impairments   51           13     50     1     12                 127  
     gains on disposal of assets   (7 )                                             (7 )
     provisions to the reserve for contingencies               4     11                             15  
     provision for redundancy incentives   10     15     30     14     2     1     29           101  
     other         (10 )   (35 )   (2 )         7     (4 )         (44 )
Special items of operating profit   54     7     148     86     3     144     36           478  
Adjusted operating profit   3,195     1,269     148     154     152     (77 )   (53 )   (12 )   4,776  
Net financial (expense) income (*)   (22 )   (1 )                     (7 )   87           57  
Net income from investments (*)   (18 )   97     31     1     47     (1 )   1           158  
Income taxes (*)   (1,851 )   (492 )   (64 )   (14 )   (68 )         22     9     (2,458 )
Tax rate (%)   58.7     36.0     35.8                                   49.2  
Adjusted net profit   1,304     873     115     141     131     (85 )   57     (3 )   2,533  
of which:                                                      
- net profit of minorities                                                   178  
- Eni's adjusted net profit                                                   2,355  
                                                       
Eni's reported net profit                                                   1,520  
Exclusion of inventory holding (gains) losses                                                   213  
Exclusion of special items                                                   622  
- non-recurring (income) charges                                                   184  
- other special (income) charges                                                   438  
Eni's adjusted net profit                                                   2,355  
     
(*)   Excluding special items.

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Contents

ENI REPORT ON THE FIRST QUARTER OF 2007

Breakdown of special charges

Fourth Quarter

 

(million euro)

 

First Quarter

2006

     

2006

 

2007

 

% Ch.


     
 
 
184     Non-recurring (income) charges                      
294     Other special charges:       32     (7 )   (39 )
102          environmental charges       64     17     (47 )
127          asset impairments       3     3        
(7 )        gains on disposal of assets       (57 )         57  
15          provisions to the reserve for contingencies       3           (3 )
101          provision for redundancy incentives       24     10     (14 )
(44 )        other       (5 )   (37 )   (32 )
478     Special items of operating profit       32     (7 )   (39 )
5     Net financial (expense) income                      
1     Net income from investments                      
      of which:                      
(73 )        gain on Galp Energia SGPS SA (disposal of gas assets to Rede Electrica National)                      
138     Income taxes       7     2     (5 )
      of which:                      
179          wind-fall tax Algeria                      
2          legal proceeding in Venezuela       38           (38 )
622     Total special items of net profit       39     (5 )   (44 )

- 38 -


Contents

 

 
       

Società per Azioni
Headquarters: Rome, Piazzale Enrico Mattei, 1
Capital Stock:
euro 4,005,358,876 fully paid
Registro delle Imprese di Roma,
codice fiscale 00484960588
Branches:
San Donato Milanese (MI) - Via Emilia, 1
San Donato Milanese (MI) - Piazza Ezio Vanoni, 1

 

    

    

Investor Relations
Piazza Ezio Vanoni, 1 - 20097 San Donato Milanese (Milan)
Tel. +39-0252051651 - Fax +39-0252031929
e-mail: investor.relations@eni.it

Internet Home page: www.eni.it
Rome office telephone: +39-0659821
Toll-free number: 800940924
e-mail: segreteriasocietaria.azionisti@eni.it

ADRs/Depositary
Morgan Guaranty Trust Company of New York
ADR Department
60 Wall Street (36th Floor)
New York, New York 10260
Tel. 212-648-3164

ADRs/Transfer agent
Morgan ADR Service Center
2 Heritage Drive
North Quincy, MA 02171
Tel. 617-575-4328

Design: Opera
Cover: Grafica Internazionale - Rome
Layout and supervision: Korus Srl - Rome
Digital printing: Mari Group Communications - Rome

 


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MISSION

We are a major integrated energy company, committed to growth in the activities of finding, producing, transporting, transforming and marketing oil and gas. Eni men and women have a passion for challenges, continuous improvement, excellence and particularly value people, the environment and integrity

 

Countries of activity

EUROPE
Austria, Belgium, Croatia, Cyprus, Czech Republic, Denmark, France, Germany, Greece, Hungary, Ireland, Italy, Luxembourg, Malta, Netherlands, Norway, Principality of Monaco, Portugal, Romania, Slovakia, Slovenia, Spain, Switzerland, Turkey, United Kingdom

CIS
Azerbaijan, Georgia, Kazakhstan, Russia, Turkmenistan

AFRICA
Algeria, Angola, Cameroon, Chad, Congo, Cote d’Ivoire, Egypt, Gabon, Libya, Mali, Morocco, Mozambique, Nigeria, Tunisia

MIDDLE EAST
Iran, Kuwait, Oman, Qatar, Saudi Arabia, United Arab Emirates

CENTRAL ASIA
India, Pakistan

SOUTH EAST ASIA AND OCEANIA
Australia, China, East Timor, Indonesia, Malaysia, Papua-New Guinea, Thailand

AMERICAS
Argentina, Brazil, Canada, Ecuador, Mexico, Peru, Trinidad & Tobago, United States, Venezuela

 

 


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Contents

Ordinary Shareholders’ Meeting of May 23 and 24, 2007

The notice convening the meeting was published on the
Gazzetta Ufficiale of the Republic of Italy
No. 44, section II of April 14, 2007 page 1 to 5




This annual report includes the report of Eni’s Board of Directors and
Eni’s consolidated financial statements for the year ended December 31,
2006, which have been prepared under the International Financial
Reporting Standards (IFRS), as adopted by the European Union.

Disclaimer
This annual report contains certain forward-looking statements in particular under the section “Outlook” regarding capital expenditure, development and management of oil and gas resources, dividends, share repurchases, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets, and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future.
Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors and other factors discussed elsewhere in this document.

 


Table of Contents

Report of the Directors

  4   Profile of the year
         
    8   Letter to Shareholders
         
        Operating Review
    12   Exploration & Production
    31   Gas & Power
    42   Refining & Marketing
    48   Petrochemical
    51   Engineering & Construction
         
    54   Financial Review
         
    82   Other Information
         
    84   Corporate Governance
         
    110   Commitment to sustainable development
         
   

126

  Glossary
         
Consolidated Financial Statements        
    129   Report of Independent Auditors
    133   Balance sheet
    134   Profit and loss account
    135   Statements of changes in shareholders’ equity
    137   Statements of cash flow
    140   Basis of presentation and accounting principles
   

151

  Notes to the Consolidated Fnancial Statements
    209   Adjustment of the Consolidated Financial Statements to U.S. GAAP
    214   Additional financial statement disclosures required by U.S. GAAP and the SEC
         

 


Contents

ENI ANNUAL REPORT / PROFILE OF THE YEAR

Profile of the year  

     
Results

In 2006 Eni delivered record earnings, up 4.9% from 2005 to euro 9.2 billion; on an adjusted base, earnings were up 12.5% to euro 10.4 billion. This result was driven by continued improvements in performance and consistent execution of Eni’s strategy, in a broadly favorable trading environment.
Total Shareholder Return for the year came in at 14.8%, one of the highest in the industry.

Dividend

2006 record earnings and cash flow, along with a sound balance sheet structure, allow a dividend distribution of euro 1.25 per share, up 13.6% from 2005 (euro 1.10 per share in 2005). Included in this annual payment is euro 0.60 per share already distributed as interim dividend in October 2006. Pay-out stands at 50%.

  Oil and natural gas production

Oil and natural gas production for the year averaged 1.77 mmboe/d, up 1.9% compared with 2005. This included the loss of production at the Venezuelan Dación oilfield (down 46 kbbl/d) and lower entitlements in certain Production Sharing Agreements (PSAs) and buy-back contracts (down 21 kbbl/d) due to higher oil and gas prices. Eni delivered its 3% production growth rate based on a $55 per barrel scenario, as announced in the 2006 quarterly production outlook. Libya, Angola and Egypt were the main growth areas.

Proved oil and natural gas reserves

Net proved reserves at December 31, 2006 stood at 6.44 bboe (down 6% compared with December 31, 2005), representing 10 years of remaining production at the current rate. Organic proved additions, as calculated by applying a year-end Brent price of $58.93 per barrel, replaced 65% of production. Assuming Brent is constant at $40 per barrel when determining entitlements in PSAs, the three-year average proved reserve replacement ratio would be 106%.

 

4


Contents

ENI ANNUAL REPORT / PROFILE OF THE YEAR

     
Natural gas sales

Natural gas sales were up approximately 4% to 97.48 bcm due primarily to the growth in sales in a number of target European markets (up approximately 16% in particular in Turkey, Germany/Austria and France) also for the build-up of supplies of natural gas from Libya, partly offset by a decrease in sales in Italy due to mild weather conditions in the fourth quarter of the year.
Sales of liquefied natural gas (LNG) were 9.9 bcm, up 41.4% from 2005.

Strategic agreement with Gazprom

In November 2006, Eni and Gazprom signed a broad strategic agreement. This alliance sets up a long term partnership enabling the two companies to launch joint projects in the mid- and downstream gas sector, in the upstream and in technological cooperation.
A key feature of this deal is the extension of the duration of Russian gas supply contracts until 2035, further strengthening Eni’s supply portfolio.

  Expansion strategy: purchase of oil producing and exploratory assets in Congo

In February 2007, Eni defined a deal with the French company Maurel & Prom to acquire producing assets and exploration licenses located onshore in Congo, entailing a cash consideration of $1.4 billion.
The deal is consistent with Eni’s strategy of purchasing proved and unproved reserves and producing assets in legacy countries where Eni can achieve synergies leveraging on its competencies and the availability of facilities.
This transaction is subject to approval by the Congolese authorities.

Exploration activity

In 2006, Eni invested euro 1,348 million in exploratory activities, up 106% from 2005, executing a huge exploration campaign leading to the completion of 68 exploratory wells (36 net to Eni) with a commercial rate of success of 43% (49% net to Eni).
A further 26 wells were in progress as of the year-end.
Eni enhanced its exploration portfolio by acquiring assets in core areas such as North Africa, West Africa, Brazil, Norway and the United States, and in new high-potential basins such as Mali, Mozambique and East Timor. New acreage covers 152,000 square kilometers (99% operated by Eni).

 

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Contents

ENI ANNUAL REPORT / PROFILE OF THE YEAR

Selected consolidated financial data  

2004

 

2005

 

2006

(euro million)  
 
 
Net sales from operations      

57,545

 

73,728

 

86,105

Operating profit      

12,399

 

16,827

 

19,327

Adjusted operating profit      

12,582

 

17,558

 

20,490

Net profit      

7,059

 

8,788

 

9,217

Adjusted net profit      

6,645

 

9,251

 

10,412

Cash flow from operations      

12,500

 

14,936

 

17,001

Capital expenditure      

7,499

 

7,414

 

7,833

Dividends pertaining to the year (a)      

3,384

 

4,086

 

4,594

Cash dividends      

2,828

 

5,070

 

4,610

Common stock purchases (gross)      

70

 

1,034

 

1,241

Research and development costs      

257

 

204

 

222

Total assets at year end      

72,853

 

83,850

 

88,312

Debts and bonds at year end      

12,684

 

12,998

 

11,699

Shareholders’ equity including minority interest at year end      

35,540

 

39,217

 

41,199

Net borrowings at year end      

10,443

 

10,475

 

6,767

Net capital employed at year end      

45,983

 

49,692

 

47,966

Share price at year end  

(euro)

 

18.42

 

23.43

 

25.48

Number of shares outstanding at year end  

(million)

 

3,770.0

 

3,727.3

 

3,680.4

Market capitalization (b)  

(billion euro)

 

69.4

 

87.3

 

93.8

   
 
 
     
(a)   Amounts due on the payment of the balance of 2006 dividend are estimated.
(b)   Number of outstanding shares by reference price at period end.

 

Key financial ratios  

2004

 

2005

 

2006

   
 
 
Profit                
- per share (a)  

(euro)

 

1.87

 

2.34

 

2.49

- per ADS (b)  

($)

 

4.66

 

5.81

 

6.26

Adjusted net profit                
- per share (a)  

(euro)

 

1.76

 

2.46

 

2.81

- per ADS (b)  

($)

 

4.38

 

6.12

 

7.07

Return On Average Capital Employed (ROACE)                
- reported  

(%)

 

16.6

 

19.5

 

20.3

- adjusted  

(%)

 

15.9

 

20.5

 

22.7

Leverage      

0.29

 

0.27

 

0.16

Dividend pertaining to the year  

(euro per share)

 

0.90

 

1.10

 

1.25

Pay-out  

(%)

 

48

 

46

 

50

Total shareholder return (TSR)  

(%)

 

28.5

 

35.3

 

14.8

Dividend yield (c)  

(%)

 

4.9

 

4.7

 

5.0

   
 
 
     
(a)   Fully diluted. Ratio of net profit and average number of shares outstanding in the year. Dollar amounts are converted on the basis of the average EUR/USD exchange rate quoted by the ECB for the periods presented.
(b)   One American Depository Share is equal to two Eni ordinary shares.
(c)   Ratio of dividend for the period and average price of Eni shares in December.

 

Trading environment indicators  

2004

 

2005

 

2006

   
 
 
Average price of Brent dated crude oil (a)      

38.22

  54.38  

65.14

Average EUR/USD exchange rate (b)      

1.244

  1.244  

1.256

Average price in euro of Brent dated crude oil      

30.72

  43.71  

51.86

Average European refining margin (c)      

4.35

  5.78  

3.79

Average European refining margin in euro      

3.50

  4.65  

3.02

Euribor - three-month euro rate  

(%)

 

2.1

  2.2  

3.1

Libor - three-month dollar rate  

(%)

 

1.6

  3.5  

5.2

   
 
 
     
(a)   In US per barrel. Source: Platt’s Oilgram.
(b)   Source: BCE.
(c)   In US per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations based on Platt’s Oilgram data.

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ENI ANNUAL REPORT / PROFILE OF THE YEAR

Selected operating data  

2004

 

2005

 

2006

   
 
 
Exploration & Production                
Net proved reserves of hydrocarbons (at December 31)  

(mmboe)

 

7,218

 

6,837

 

6,436

- Liquids  

(mmbbl)

 

4,008

 

3,773

 

3,481

- Natural gas  

(bcf)

 

18,435

 

17,591

 

16,965

Average reserve life index  

(year)

 

12.1

 

10.8

 

10.0

Production of hydrocarbons  

(kboe/d)

 

1,624

 

1,737

 

1,770

- Liquids  

(kbbl/d)

 

1,034

 

1,111

 

1,079

- Natural gas  

(mmcf/d)

 

3,387

 

3,595

 

3,966

Gas & Power                
Worldwide gas sales  

(bcm)

 

87.03

 

94.21

 

97.48

Total gas sales in Europe  

(bcm)

 

85.32

 

92.50

 

95.97

- G&P division sales  

(bcm)

 

80.62

 

87.99

 

91.90

- Upstream sales (a)  

(bcm)

 

4.70

 

4.51

 

4.07

Customers in Italy  

(million)

 

5.95

 

6.02

 

6.54

Gas volumes transported in Italy  

(bcm)

 

80.41

 

85.10

 

87.99

Electricity production sold  

(TWh)

 

13.85

 

22.77

 

24.82

Refining & Marketing                
Refining throughputs on own account  

(mm tonnes)

 

37.69

 

38.79

 

38.04

Refining throughputs of wholly-owned refineries  

(mm tonnes)

 

26.75

 

27.34

 

27.17

Balanced capacity of wholly-owned refineries  

(kbbl/d)

 

504

 

524

 

534

Balanced capacity utilization rate  

(%)

 

100

 

100

 

100

Sales of petroleum products on Agip branded network in Europe  

(mm tonnes)

 

12.35

 

12.42

 

12.48

Agip branded service stations in Europe at period end  

(units)

 

6,225

 

6,282

 

6,294

Average throughput of Agip branded network in Europe  

(k liters/y)

 

2,488

 

2,479

 

2,470

Petrochemical                
Production  

(k ton)

 

7,118

 

7,282

 

7,072

Sales  

(k ton)

 

5,187

 

5,376

 

5,276

Average capacity utilization rate  

(%)

 

75.2

 

78.4

 

76.4

Engineering & Construction                
Orders acquired  

(euro million)

 

5,784

 

8,395

 

11,172

Order backlog at period end  

(euro million)

 

8,521

 

10,122

 

13,191

Employees at period end  

(units)

 

70,348

 

72,258

 

73,572

       
 
 
     
(a)   Does not include Eni’s share of Nigerian LNG (Eni 10.4%) sales in Europe amounting to 1.30; 1.31; 1.55 bcm; in 2004, 2005 and 2006, respectively.

 

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ENI ANNUAL REPORT / LETTER TO SHAREHOLDERS

Eni’s Board of Directors

     
         
    Roberto Poli
Chairman
  Paolo Scaroni
CEO

 

To our Shareholders


2006 was a remarkable year for Eni in terms of both financial performance and operational accomplishments
Our earnings and cash flow were the highest in our history, driven by continued improvements in performance and consistent execution of our strategy in a broadly favourable trading environment.
In particular, we maintained pleasing production growth despite the impact of disruption in Venezuela, achieved several exploration successes, secured access to promising new acreage and further expanded our global natural gas business.
On top of that, we struck a landmark agreement with Gazprom which extends our gas contracts to 2035 and opens up new opportunities for upstream expansion in Russia.

Financial performance
Our reported net profit of euro 9.2 billion in 2006 was the highest in the history of the Company.
Adjusted net profit rose 12.5% to euro 10.4 billion, representing a return on average capital employed of 22.7%. Net cash generated by operating activities totalled euro 17 billion, allowing us to finance capital expenditure of euro 7.8 billion and to reduce our debt/equity ratio to 0.16. Those strong results enabled us to propose a dividend of euro 1.25 per share to our Annual General Shareholders’ Meeting, up 14%
  compared to 2005 (euro 1.10 per share), of which euro 0.60 was paid as an interim dividend in October 2006. During the year, we purchased a total of 53.1 million of our own shares for euro 1.2 billion, bringing the total cash returned to shareholders for the year to euro 5.8 billion. Our total shareholder return was 14.8%, making this the fifth year running that we have outperformed our peer group.

Sustaining growth and shareholder return
Growth is at the heart of our strategic priorities.
A strong pipeline of projects and investment opportunities will enable us to achieve our ambitious short and long-term growth targets.
Over the next four years, we will invest euro 44.6 billion in our businesses to ensure our continued growth, also beyond 2010.
This investment program, the largest ever in Eni’s history, will be carried out with tight financial discipline.
The projected free cash flow in 2010 will allow us to sustain the current flow of dividends in real terms, even with a scenario of 40$/bl Brent.

Among Eni’s business divisions, EXPLORATION & PRODUCTION showed the strongest growth.
In 2006, the division’s adjusted net profit increased by 17.7% to euro 7.3 billion. Oil and gas production rose by approximately 2% to 1.77 million boepd.
This increase was entirely organic and was achieved despite the negative impact of the unilateral

 

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ENI ANNUAL REPORT / LETTER TO SHAREHOLDERS

 

     
             
Alberto Clô
Director
  Renzo Costi
Director
  Dario Fruscio
Director
  Marco Pinto
Director

 

termination of the Dación contract in Venezuela and the adverse entitlement effects in PSAs and buyback contracts due to higher oil prices. Excluding the effect of higher oil prices on PSAs and the termination of the Dación contract, organic production growth was close to an impressive 6%. We are committed to maintaining strong organic production growth.
The company targets a production level of 2 million boepd by 2010, with an average growth rate of approximately 3% per year.

Exploration activity reaped substantial results in 2006, reaching an average success rate of 49% and adding 152,000 sq km of net acreage, 99% operated.
Over the medium term, we are committed to replacing more than 100% of produced reserves.
Development activities are progressing in many fields around the world, including Kashagan, where we expect higher capex and a longer timetable.
However, we have also been able to confirm that the field is capable of higher production levels than previously thought.

We are progressing with the global expansion of the LNG business as a way to monetize our large gas reserve base. Major steps taken in 2006 include the start-up of train five at the Bonny liquefaction plant in Nigeria, where a sixth train will commence operations in 2008, and the signing of a framework agreement for doubling the capacity of the Damietta liquefaction plant in Egypt by 2010.
  The growth options we are presently pursuing with our partner Gazprom could potentially enable us to accelerate the achievement of our growth targets.

In GAS & POWER, our strong and integrated position in Europe generates stable and robust earnings and cash flows. Adjusted net profit for the year rose by 12.1% to euro 2.9 billion, supported by an approximately 16% increase in volumes sold in Europe (excluding Italy) to 35 bcm (excluding gas sold by E&P of 4 bcm).
This result was achieved despite stiff competition and mild weather.

Our strategy is based on growing our market share in key European markets, preserving our domestic natural gas business and effectively managing our regulated business. European natural gas demand is forecast to grow steadily in the future, resulting in a cumulative increase of around 45% by 2020 (2.4% per annum).
This, coupled with the decline of Europe’s internal production, means that our continent will become more and more reliant on external supplies to fulfil its gas needs. In this context, Eni is poised to further strengthen its market leadership by leveraging on an unparalleled portfolio of assets in terms of infrastructure, availability of gas – both equity and purchased under long term supply contracts – long-standing relationships with natural gas producing countries, market knowledge and a large customer base. The recent alliance with Gazprom marks a new milestone in our relationship with the largest natural

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ENI ANNUAL REPORT / LETTER TO SHAREHOLDERS

   
         
Marco Reboa
Director
  Mario Resca
Director
  Pierluigi Scibetta
Director

 

gas producer in the world, and will enable us to reinforce our competitive profile.
By 2010 we are committed to selling more than 105 bcm of gas worldwide, with sales outside Italy expected to grow at an average rate of 10% per year.

Our REFINING & MARKETING division reported an adjusted net profit of euro 629 million, which was 33.4% lower than in 2005 due to the weak refining margin environment, the appreciation of the euro against the dollar and the impact of higher levels of planned maintenance activity.

Looking forward, several trends are emerging in the refining landscape: the adoption of increasingly strict environmental standards, global imbalances in product availability (especially a deficit of diesel fuel in Europe), a relative abundance of heavy crude and the desire to increase efficiency. These are the key drivers of our strategy.

In Refining, Eni will increase its capital expenditure to enhance the refinery conversion rate in order to meet future product quality requirements, produce higher-value products and chemical feedstocks, lower operating costs and increase refinery flexibility in processing low-quality crude oils. In Marketing, we aim to extract full value from our retail business in Italy through a selective investment program, customer-focused marketing initiatives, effective differentiation of pricing, an improved premium-products offer, and operating efficiencies.
  In managing our PETROCHEMICAL operations, which reported an adjusted net profit of euro 174 million for 2006, we remain committed to improving efficiency and selectively developing those plants with sufficient scale and a favourable geographic location.
Capital expenditure will be focussed on implementing de-bottlenecking projects, enhancing the efficiency and flexibility of plants in areas of excellence (styrenes and elastomers) and maintaining high standards of health, safety, security and environmental performance.

In ENGINEERING & CONSTRUCTION, adjusted net profit rose by 22% to euro 400 million, reflecting the strong competitive position held by Saipem, also as a result of the integration of Snamprogetti. To cope with rising demand for drilling equipment and oilfield services, Saipem is planning to further expand the geographical reach and operational features of its world-class fleet.

Our relentless commitment to technological research and innovation underscores a fundamental belief that technology is key to increasing our competitive advantage over the long term and promoting sustainable growth. We are conducting research aimed primarily at reducing the costs of finding and recovering hydrocarbons, upgrading heavy oils, monetizing stranded gas and protecting the environment. In particular we are moving forward on our breakthrough technologies: EST (Eni Slurry Technology) for the full exploitation of the heavy barrel, TAP (gas transportation at high pressure) and GTL (gas-to-liquids) for gas monetization.

 

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ENI ANNUAL REPORT / LETTER TO SHAREHOLDERS

Sustainable development
2006 marks the first year in which Eni has published a Sustainability Report to communicate more effectively with stakeholders. We now have a more coherent approach to sustainability, and are even more committed to managing and developing your company in a responsible and accountable way. Among the various initiatives, our focus is on reducing greenhouse
  gas emissions from industrial processes and developing projects to economically exploit flared gas.

In conclusion, 2006 was a very good year for Eni. As well as delivering impressive results, we have worked to create future growth opportunities in all our divisions. We are confident that we can continue to deliver industry-leading growth and superior shareholder returns.

March 29, 2007

In representation of the Board of Directors

Chairman Chief Executive Officer and General Manager

 

BOARD OF DIRECTORS (1)   BOARD OF STATUTORY AUDITORS (7)
Chairman   Chairman
Roberto Poli (2)   Paolo Andrea Colombo
Chief Executive Officer   Statutory Auditors
Paolo Scaroni (3)   Filippo Duodo, Edoardo Grisolia, Riccardo Perotta, Giorgio Silva
Directors   Alternate Auditors
Alberto Clô, Renzo Costi, Dario Fruscio, Marco Pinto, Marco Reboa, Mario Resca, Pierluigi Scibetta   Francesco Bilotti, Massimo Gentile
     
GENERAL MANAGERS   MAGISTRATE OF THE COURT OF ACCOUNTS
Exploration & Production Division   DELEGATED TO THE FINANCIAL CONTROL OF ENI
Stefano Cao (4)   Lucio Todaro Marescotti (8)
Gas & Power Division   Alternate
Domenico Dispenza (5)   Angelo Antonio Parente (9)
Refining & Marketing Division   External Auditors (10)
Angelo Taraborelli (6)   PricewaterhouseCoopers SpA

The composition and powers of the Internal Control Committee, Compensation Committee and International Oil Committee are presented in the section “Corporate Governance” in the Report of the Directors.

(1)   Appointed by the Shareholders’ Meeting held on May 27, 2005 for a three-year period. The Board of Directors expires at the date of approval of the financial statements for the 2007 financial year.
(2)   Appointed by the Shareholders’ Meeting held on May 27, 2005.
(3)   Powers conferred by the Board of Directors on June 1, 2005.
(4)   Appointed by the Board of Directors on November 14, 2000.
(5)   Appointed by the Board of Directors on December 14, 2005, effective from January 1, 2006.
(6)   Appointed by the Board of Directors on April 14, 2004.
(7)   Appointed by the Shareholders’ Meeting held on May 27, 2005 for a three-year period, expiring at the date of approval ot the financial statements for the 2007 financial year.
(8)   Duties assigned by resolution of the Governing Council of the Court of Accounts on July 19-20, 2006.
(9)   Duties assigned by resolution of the Governing Council of the Court of Accounts on May 27-28, 2003.
(10)   Appointed by the Shareholders’ Meeting of May 28, 2004 for the 2004-2006 three year term.

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ENI ANNUAL REPORT / OPERATING REVIEW

Exploration & Production

 

Key performance indicators  

2004

 

2005

 

2006 (a)

   
 
 
Net sales from operations (b)  

(million euro)

 

15,346

 

22,531

 

27,173

Operating profit      

8,185

 

12,592

 

15,580

Adjusted operating profit      

8,202

 

12,903

 

15,763

Adjusted net profit      

4,033

 

6,186

 

7,279

Capital expenditure      

4,853

 

4,965

 

5,203

of which: exploration (c)      

499

 

656

 

1,348

Capital employed, net      

17,937

 

20,206

 

18,590

ROACE adjusted  

(%)

 

22.7

 

32.4

 

37.5

Average realizations                
- Liquids  

($/bbl)

 

34.73

 

49.09

 

60.09

- Natural gas  

($/mmcf)

 

3.89

 

4.49

 

5.29

- Total hydrocarbons  

($/boe)

 

30.40

 

41.06

 

48.87

Production                
- Liquids  

(kbbl/d)

 

1,034

 

1,111

 

1,079

- Natural gas  

(mmcf/d)

 

3,387

 

3,595

 

3,966

- Total hydrocarbons  

(kboe/d)

 

1,624

 

1,737

 

1,770

Net proved reserves                
- Liquids  

(mmbbl)

 

4,008

 

3,773

 

3,481

- Natural gas  

(bcf)

 

18,435

 

17,591

 

16,965

- Total hydrocarbons  

(mmboe)

 

7,218

 

6,837

 

6,436

Reserve life index  

(year)

 

12.1

 

10.8

 

10.0

Proved reserve replacement ratio  

(%)

 

105

 

23

 

65

Employees at year end  

(unit)

 

7,477

 

8,030

 

8,336

       
 
 
     
(a)   Starting January 1, 2005, Eni's subsidiary Tecnomare has been reported within the Exploration & Production segment. In previous years, it was reported within the aggregate "Other activities".
(b)   Before elimination of intersegment sales.
(c)   Includes exploration bonus.

 

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ENI ANNUAL REPORT / OPERATING REVIEW

Acquisition of operated assets in Congo
› On February 2007, Eni purchased exploration and production onshore activities operated by Maurel & Prom in Congo, entailing a cash consideration of $1.4 billion. This deal is consistent with Eni’s strategy of purchasing proved and unproved reserves and producing assets in legacy countries where Eni can achieve synergies leveraging on own competencies and the availability of facilities. This transaction is subject to approval by the Congolese authorities

Financial results
› Adjusted net profit was euro 7,279 million, up euro 1,093 million from a year ago (+17.7%), reflecting an enhanced operating profit as a result of higher oil and natural gas realization in dollars combined with increased production volumes sold. These positives were offset in part by higher operating costs and a higher adjusted tax rate

› Return on average capital employed calculated on an adjusted basis was 37.5% in 2006, higher that in 2005 (32.4%)

› In 2006, price differentials between equity realizations and the price of the Brent crude marker were equal to minus $3.63 per barrel, improving from 2005 levels, as a result of appreciation on the market of oil produced in Angola and higher realizations recorded on Kazakh oil. Natural gas prices increased in virtually all areas, reflecting higher prices for oil and products

› Eni invested euro 3.6 billion in the development of oil and natural gas reserves, in particular in Kazakhstan, Angola, Egypt and Italy, and euro 1.4 billion (up 106% compared with 2005) in exploration activities, in particular in Angola, Egypt, Nigeria, the Norwegian offshore and the Gulf of Mexico

Production
› Oil and natural gas production for the year averaged 1.77 mmboe/d, up 1.9% from 2005. This included the loss of production at the Venezuelan Dación oilfield and lower entitlements in certain Production Sharing Agreements (PSAs) and buy-back contracts1 due to higher oil and gas prices. Eni delivered its 3% production growth rate based on a $55 per barrel scenario, as announced in the 2006 quarterly production outlook

› Production increases were driven primarily by start-ups/full production of large gas projects in Libya (achievement of full production at the Bahr Essalam field in the Western Libyan Gas Project), Nigeria (start-up of trains 4 and 5 of the Bonny LNG plant), Egypt (development of offshore reserves in the Nile Delta), Australia (start-up of the gas phase of the Bayu-Undan field), Croatia (start-up of the Ika, Ida and Ivana C-K fields) and liquid production growth in Angola and Libya

› In the medium term, Eni expects to deliver a 3% compound average growth rate from 2007 to 2010, targeting a production level in excess of 2 mmboe/d by 2010

 


     
(1)   For a definition of PSA and buy-back contracts see "Glossary" below.

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ENI ANNUAL REPORT / OPERATING REVIEW

Net proved reserves
› Net proved reserves at December 31, 2006 stood at 6.44 bboe (down 6% compared with December 31, 2005), representing 10 years of remaining production at the current rate. Organic proved additions, as calculated by applying a year-end Brent price of $58.93 per barrel, replaced 65% of production. Assuming Brent is constant at $40 per barrel when determining entitlements in PSAs, the three-year average proved reserve replacement ratio would be 106%

› In the medium term, management expects Eni’ s reserve replacement ratio to be supported by the high mineral potential of assets located in core areas such as the Caspian Sea, West and North Africa

Exploration activities and renewal of mineral right portfolio
› Eni carried out several hydrocarbon discoveries, mainly in Indonesia, Egypt, Kazakhstan, Norway, Nigeria, United Kingdom, the Gulf of Mexico, Italy, Angola and Congo. A total of 68 exploratory wells were completed (35.9% net to Eni), with a commercial rate of success of 43% (49% net to Eni). Other 26 wells are in progress as of year-end

› Eni’s exploration portfolio was strengthened through acquisition of assets in both core areas such as Angola, Alaska, Brazil, Congo, Egypt, Nigeria, Norway, Pakistan, the Gulf of Mexico and new countries/areas with a high mineral potential such as Mali, Mozambique and East Timor. Gross acquired acreage extends for approximately 259,000 square kilometers (152,000 net to Eni, 99% operated)

 

Reserves
Reserve Governance
The Company has adopted comprehensive classification criteria for proved, proved developed and proved undeveloped oil and gas reserves in accordance with applicable U.S. Securities and Exchange Commission (SEC) regulations, as provided for in Regulation S-X, Rule 4-10.
Proved oil and gas reserves are the estimated quantities that geologic and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. Engineering estimates of the Company’s oil and gas reserves are inherently uncertain. Although authoritative guidelines exist regarding engineering criteria that have to be met before estimated oil and gas reserves can be designated as “proved”, the accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Consequently, the estimated proved reserves of oil and natural gas may be subject to future revision and upward and downward revisions may be made to the initial booking of reserves
  due to analysis of new information concerning production, reservoir performance, commercial factors, acquisition and divestment activity and additional reservoir development activity.
Field resources will only be categorized as proved reserves when all criteria for the attribution of proved status has been met, including technical, economic and commercial criteria.
Proved reserves to which Eni is entitled under concession contracts are determined by applying Eni’s share of production to total proved reserves of the contractual area, in respect of the duration of the relevant mineral right that normally coincides with the duration over which a field can be produced economically.
Proved reserves to which Eni is entitled under Production Sharing Agreements or buy-back contracts are calculated so that the sale of production entitlements should cover expenses incurred by the Group to develop a field (cost oil) and on the profit oil set contractually. A similar scheme applies to buy-back and service contracts. In a high oil price environment, the volume of entitlements necessary to cover the same amount of expenses is lower.
Eni has always exercised rigorous control over the booking process of proved reserves. The Reserve

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ENI ANNUAL REPORT / OPERATING REVIEW

Department of the Exploration & Production division, reporting directly to the General Manager, is entrusted with the task of continuously updating the Company’s guidelines concerning reserve evaluation and monitoring the periodic quantification process. Company guidelines have been reviewed by DeGolyer and MacNaughton (D&M), an independent petroleum engineers company which has declared their compliance with applicable SEC rules. D&M has also stated that the company guidelines regulate situations for which the SEC rules are less precise, providing a reasonable interpretation in line with the generally accepted practices in international markets.
Eni estimates its proved reserves on the basis of the mentioned guidelines, also when participating in
  exploration and production activities operated by other entities. The process for evaluating reserves involves: (i) business unit managers (geographic units) and Local Reserve Evaluators (LRE), who perform the evaluation and classification of technical reserves (production profiles, capital expenditure, operating costs and costs related to asset retirement obligations); (ii) geographic area managers at head offices checking evaluations carried out by business unit managers; (iii) the Reserve Department, providing independent reviews of the fairness and correctness of classifications carried out by business units, who also aggregates worldwide reserve data and calculates equity volumes. Moreover, the Reserve Department has the following responsibilities: to ensure the periodic certification
     
     
process of reserves, to perform economic evaluation of reserves and to continuously update the Company guidelines on reserves evaluation and classification.
All personnel involved in the process of reserve evaluation are knowledgeable on SEC guidelines for proved reserves classification and have professional abilities adequate to the complexity of the task, expressing their judgment independently and respectful of professional ethics.
Since 1991, Eni has employed qualified independent petroleum engineers companies to perform independent evaluations2 of its proved reserves on a
  rotational basis. In particular, in 2006, a total of 1.4 billion boe of proved reserves was evaluated, representing 21% of Eni’s total proved reserves at December 31, 2006. Outcomes of these independent evaluations confirmed Eni’s evaluations, as they did in previous years. During the 2004-2006 three year period, independent evaluations covered 76% of Eni’s total proved reserves. Further information on reserves is provided in Note 35 to Eni consolidated financial statements – “Supplemental oil and gas information for the exploration and production activities – Oil and natural gas reserves”.

     
(2)   From 1991 to 2002, DeGolyer and MacNaughton; from 2003, also Ryder Scott.

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ENI ANNUAL REPORT / OPERATING REVIEW

 
Algeria: Drilling unit

 

Evolution of proved reserves
Eni’s net proved reserves of oil and natural gas at December 31, 2006 totaled 6,436 mmboe (oil and condensates 3,481 mmbbl; natural gas 2,955 mmboe). These reserves are located in Italy (12% of Eni’s total proved reserves); North Africa (32%; in particular in Libya, Egypt and Algeria); West Africa (17%; in particular in Nigeria and Angola); the North Sea (11%; Norway and the United Kingdom) and Rest of World (28%; in particular in Kazakhstan, Pakistan, Australia and Ecuador).
At December 31, 2006, proved reserves associated with PSAs represented 53% of total proved reserves (48% as at December 31, 2005). Proved reserves associated with service and buy-back contracts represented 2% of all proved reserves at December 31, 2006 (2% at December 31, 2005).
Additions to proved reserves booked in 2006 were 417 mmboe deriving from: (i) extensions and discoveries (161 mmboe), in particular in Kazakhstan, Algeria,
  Egypt, Trinidad & Tobago and Libya; (ii) improved recovery (105 mmboe), in particular in Egypt, Angola, Algeria, Kazakhstan and Nigeria; (iii) revisions of previous estimates (up 151 mmboe) related to upward revisions registered in Kazakhstan, Libya and Egypt, offset in part by downward revisions in Nigeria and Ecuador.
The unilateral cancellation of the service contract for the Dación oilfield by the Venezuelan state oil company PDVSA determined a decrease in Eni’s proved reserves of 170 mmbbl (see Venezuela below).
In 2006 Eni’s proved reserves replacement ratio was 65% (38% all sources, including the loss of proved reserves at the Venezuelan Dación oilfield and other disposals) representing 10 years of remaining production at the current rate (10.8 as at December 31, 2005). Considering the adverse entitlement impact in certain PSAs and buy-back contracts resulting from higher oil prices (Brent price was $58.925 per barrel at December 31, 2005) and assuming Brent constant at

 

Evolution of proved reserves in the year  

(million boe)

     
Net proved reserves at December 31, 2005        

6,837

 
Revisions, extensions and discoveries and improved recovery  

417

       
Production for the year  

(646

)  

(229

)
         

6,608

 
Purchase of proved property        

(2

)
Unilateral cancellation by PDVSA of the contract concerning the Dación field         (170 )
Net proved reserves at December 31, 2006        

6,436

 

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ENI ANNUAL REPORT / OPERATING REVIEW

$40 per barrel when determining entitlements in PSAs, the three-year average proved reserve replacement ratio would be 106%.
At December 31, 2006, Eni’s proved developed reserves stood at 4,059 mmboe (oil and condensates 2,144 mmbbl, natural gas 1,915 mmboe) or 63% of total proved reserves (63% at December 31, 2005).

  Mineral right portfolio
and exploration activities

As of December 31, 2006, Eni’s mineral right portfolio consisted of 1,029 exclusive or shared rights for exploration and development in 36 countries on five continents for a total net acreage of 385,219 square kilometers (266,000 at December 31, 2005). Of these, 48,273 square kilometers concerned production and development (55,098 at December 31, 2005). Outside Italy net acreage (362,723 square kilometers) increased by 120,775 square kilometers mainly due to the acquisition of assets after international bid procedures in Angola, Australia, Brazil, Congo, Egypt, Morocco, Nigeria, Norway, Pakistan and the United States, as well as in the new countries/areas of Mali, Mozambique and East Timor.
In Italy, net acreage (22,496 square kilometers) declined by 1,557 square kilometers due to releases.

In 2006, a total of 68 new exploratory wells were drilled (35.9 of which represented Eni’s share), as compared to 52 exploratory wells completed in 2005 (21.8 of which represented Eni’s share). Overall commercial success rate was 43% (49% net to Eni) as compared to 39.3% (47.4% net to Eni) in 2005.

 

Net proved hydrocarbon reserves (a) (b)
    Liquids   Natural gas   Hydrocarbons   Liquids   Natural gas   Hydrocarbons   Liquids   Natural gas   Hydrocarbons  

Change

    (mmbbl)   (bcf)   (mmboe)   (mmbbl)   (bcf)   (mmboe)   (mmbbl)   (bcf)   (mmboe)  

Ch.

 

%

    2004   2005   2006   2006 vs 2005
   
 
 
 
Italy  

225

 

3,818

 

890

 

228

 

3,676

 

868

 

215

 

3,391

 

805

 

(63

)  

(7.3

)
North Africa  

993

 

6,453

 

2,117

 

979

 

6,132

 

2,047

 

998

 

5,963

 

2,037

 

(10

)  

(0.5

)
West Africa  

1,056

 

1,729

 

1,357

 

942

 

1,967

 

1,285

 

793

 

1,929

 

1,129

 

(156

)  

(12.1

)
North Sea  

450

 

2,051

 

807

 

433

 

1,864

 

758

 

386

 

1,697

 

682

 

(76

)  

(10.0

)
Rest of World  

1,284

 

4,384

 

2,047

 

1,191

 

3,952

 

1,879

 

1,089

 

3,985

 

1,783

 

(96

)  

(5.1

)
Total  

4,008

 

18,435

 

7,218

 

3,773

 

17,591

 

6,837

 

3,481

 

16,965

 

6,436

 

(401

)  

(5.9

)
   
 
 
 
 
 
 
 
 
 

 

     
(a)   The conversion rate of natural gas from cubic feet to boe is 1,000 cubic feet = 0.1742 barrels of oil.
(b)   Includes Eni's share of proved reserves of equity-accounted entities (36 mmboe in 2006).

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Production
In 2006 oil and gas production averaged 1,770 kboe/d, up 32 kboe from 2005 or 1.9%, despite the impact of the production loss in the Dación oil field in Venezuela (down 46 kboe/d) and of adverse entitlement effects (down 21 kboe/d) in PSAs and buy-back contracts due to higher oil prices. Libya, Egypt, Nigeria, Australia and Croatia were the main growth areas in natural gas, while oil production increased in Angola and Libya. Declines in production were attributable to mature fields and technical problems in Nigeria due to social
 

unrest. Production outside Italy covered 87% of the total (85% in 2005).
Daily oil and condensates production for the year (1,079 kbbl/d) increased mainly in: (i) Angola due to the production ramp-up at the Kissanje and Dikanza fields in Phase B of the development of Kizomba in Block 15 (Eni's interest 20%) and the start-up of the Benguela/Belize/Lobito/Tomboco fields in Block 14 (Eni's interest 20%); (ii) Libya, due to the ramp-up of the Bahr Essalam offshore field (Eni's interest 50%) as part of the Western Libyan Gas Project and the El Feel

 

Hydrocarbon production (a) (b)
    Liquids   Natural gas   Hydrocarbons   Liquids   Natural gas   Hydrocarbons   Liquids   Natural gas   Hydrocarbons  

Change

    (kbbl/d)   (mmcf/d)   (kboe/d)   (kbbl/d)   (mmcf/d)   (kboe/d)   (kbbl/d)   (mmcf/d)   (kboe/d)  

Ch.

 

%

    2004   2005   2006   2006 vs 2005
   
 
 
 
Italy  

80

 

1,098.3

 

271

 

86

 

1,002.9

 

261

 

79

 

907.6

 

238

 

(23

)  

(8.8

)
North Africa  

261

 

681.6

 

380

 

308

 

988.8

 

480

 

329

 

1,299.6

 

555

 

75

   

15.6

 
Egypt  

94

 

607.4

 

200

 

90

 

706.3

 

213

 

85

 

812.3

 

227

 

14

   

6.6

 
Libya  

89

 

45.9

 

97

 

120

 

254.3

 

164

 

144

 

452.0

 

222

 

58

   

35.4

 
Algeria  

86

 

17.7

 

88

 

86

 

14.1

 

88

 

88

 

21.2

 

91

 

3

   

3.4

 
Tunisia  

12

 

10.6

 

15

 

12

 

14.1

 

15

 

12

 

14.1

 

15

           
West Africa  

285

 

176.6

 

316

 

310

 

190.7

 

343

 

322

 

282.5

 

372

 

29

   

8.5

 
Nigeria  

134

 

155.4

 

161

 

123

 

165.9

 

152

 

106

 

247.2

 

149

 

(3

)  

(2.0

)
Angola  

78

 

10.6

 

80

 

122

 

17.7

 

124

 

151

 

24.7

 

156

 

32

   

25.8

 
Congo  

72

 

10.6

 

74

 

65

 

7.1

 

67

 

65

 

10.6

 

67

           
Gabon  

1

     

1

                                   
North Sea  

203

 

603.9

 

308

 

179

 

600.4

 

283

 

178

 

596.8

 

282

 

(1

)  

(0.4

)
Norway  

102

 

236.6

 

143

 

96

 

243.7

 

138

 

98

 

243.7

 

140

 

2

   

1.4

 
United Kingdom  

101

 

360.2

 

164

 

83

 

356.7

 

145

 

80

 

353.1

 

142

 

(3

)  

(2.1

)
Netherlands      

7.1

 

1

                                   
Rest of world  

205

 

826.3

 

349

 

228

 

812.3

 

370

 

171

 

879.3

 

323

 

(47

)  

(12.7

)
Australia  

21

     

21

 

21

 

3.5

 

22

 

18

 

49.4

 

26

 

4

   

18.2

 
China  

5

     

5

 

7

     

7

 

6

 

10.6

 

8

 

1

   

14.3

 
Croatia      

35.3

 

6

     

42.4

 

7

     

67.1

 

12

 

5

   

71.4

 
Ecuador  

19

     

19

 

17

     

17

 

15

     

15

 

(2

)  

(11.8

)
Indonesia  

4

 

173.0

 

34

 

3

 

137.7

 

27

 

2

 

116.5

 

23

 

(4

)  

(14.8

)
Iran  

9

     

9

 

35

     

35

 

29

     

29

 

(6

)  

(17.1

)
Kazakhstan  

54

 

194.2

 

88

 

64

 

222.5

 

102

 

64

 

229.5

 

103

 

1

   

1.0

 
Pakistan  

1

 

257.8

 

46

 

1

 

275.5

 

49

 

1

 

289.6

 

51

 

2

   

4.1

 
United States  

25

 

109.5

 

44

 

19

 

74.2

 

33

 

21

 

63.6

 

32

 

(1

)  

(3.0

)
Trinidad & Tobago      

56.5

 

10

     

56.5

 

10

     

53.0

 

9

 

(1

)  

(10.0

)
Venezuela  

67

     

67

 

61

     

61

 

15

     

15

 

(46

)  

(75.4

)
Total  

1,034

 

3,386.7

 

1,624

 

1,111

 

3,595.1

 

1,737

 

1,079

 

3,965.9

 

1,770

 

33

   

1.9

 
   
 
 
 
 
 
 
 
 
 

 

     
(a)   Includes natural gas consumed in operations (283, 247, 212 mmcf/d, in 2006, 2005 and 2004, respectively).
(b)   Includes Eni's share of production of equity-accounted entities.

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field (Eni's interest 23.3%). Production decreased in Venezuela, Nigeria, despite obtaining full production at the Bonga field in OML 118 permit (Eni's interest 12.5%) and Italy due to technical problems occurred at the FPSO unit in the Aquila field and to production declines of mature fields.
Daily production of natural gas for the year (3,962 mmcf/d) increased mainly in: (i) Libya, due to the reaching of full production at the Bahr Essalam offshore field (Eni's interest 50%); (ii) Egypt, for full production/start-up of the Barboni, Baltim North, and Anshuga fields and the increase in the number of production wells at the el Temsah 4 platform in the offshore of the Nile Delta and increased supplies to the Damietta liquefaction plant (Eni's interest 40%); (iii) Nigeria, due to increased supplies to the Bonny LNG plant (Eni's interest 10.4%) related to the start-up of trains 4 and 5; (iv) Australia, due to the start-up of supplies to the Darwin liquefaction plant linked to the Bayu Undan liquid and gas field (Eni's interest 12.04%); (v) Croatia, due to the start-up of the Ika, Ida and Ivana C-K fields (Eni's interest 50%) in the Adriatic offshore. These increases were offset in part by a decline registered in Italy resulting from the production decline of mature fields.
Oil and gas production sold amounted to 625.1 mmboe. The 20.8 mmboe difference over production (645.9 mmboe) reflected volumes of gas consumed in operations (18.4 mmboe).
Approximately 68% of oil and condensate production sold (391.1 mmbbl) was destined to Eni’s Refining & Marketing segment; 40% of natural gas production sold (1,346 bcf) was destined to Eni’s Gas & Power segment.


Main exploration and development projects

NORTH AFRICA
Algeria Main discoveries for the year were: a) in onshore Block 403a (Eni’s interest 100%), the appraisal wells Rom N2 and N3 found oil at a depth of about 3,300 meters; b) in onshore Block 404a (Eni’s interest 25%), the BBKS-1 discovery well showed the presence of oil at a depth of 3,160 meters which yielded 700 barrels/d in test production; the appraisal well BBKSE-1 showed the presence of oil at a depth of about 3,200 meters and confirmed the eastward extension of the BBKS structure.

The main ongoing development projects are: (i) the ROM flaring down project (Eni’s interest 100%), targeting a 90% decrease in current volumes of flared gas at the ROM satellite center, in accordance with

 

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Egypt: Abu Rudeis field, Production unit

 

Algerian law; (ii) the ROM and ZEA Integrated Development project (Eni’s interest 100% and 75%, respectively), aiming at developing reserves recently confirmed by the appraisal work by means of water re-injection to support pressure in field. Peak production is expected at 21 kbbl/d (12 net to Eni) in 2010; (iii) El Merk Synergy project with start-up expected in 2010. Leveraging on synergies with the development of reserves in Block 208, 212, 405a and 404, the project provides for the construction of a central facility which will produce stabilized oil, condensates and NGL with an initial level of production at 144 kboe/d (19 net to Eni) in 2010. In 2006, 85% of basic engineering work was completed.
Algeria is currently reviewing the fiscal regime applicable to oil companies. With regard to the legislative text already enacted, fiscal terms applicable to existing PSAs to which foreign oil companies are parties have not been directly modified. Nevertheless, Sonatrach, the State oil company is currently bearing higher taxation on behalf of foreign oil companies.
On this basis, Sonatrach intends to renegotiate the economic terms of certain PSAs to which Eni or other Eni co-venture partners are party. According to Sonatrach, renegotiation of contractual terms is necessary in order to restore the initial economics of such contracts. At present, management is not able to foresee the final outcome of such renegotiations. In addition, the Algerian parliament with the Decree No. 06-440 of December 2, 2006 enacted the procedure, the application framework and the calculation methodology of a windfall tax charged to foreign oil companies as approved by the local Government. Effective August 1, 2006, said windfall tax applies to the extent that oil prices exceed $30 per
 

barrel and foresees rates ranging from 5 to 50% depending on the share of production to which a foreign company is entitled and the contractual scheme in force with Sonatrach. In 2006, the application of such tax entailed higher current taxation and a deferred tax charge for a total of euro 328 million impacting Eni’s accounts.

Egypt Main discoveries for the year were in: a) offshore Abu Rudeis permit (Eni’s interest 100%) the Abu Rudeis Marine 4 discovery well showing the presence of liquids at a depth of over 3,000 meters; the well was linked to existing production facilities; b) onshore West Razzak permit (Eni’s interest 80%) the Aghar SW-1X discovery well showed the presence of high quality liquids at a various levels at a depth between 1,800 and 2,300 meters; c) offshore West Baltim permit (Eni’s interest 100%) the Meret 1 and 2 discovery wells showed the presence of natural gas and condensates at various levels at depth between 1,500 and over 3,000 meters; d) offshore Thekah permit (Eni 50%) the Thekah North 1 discovery well showed the presence of natural gas at a depth between 1,350 and 1,650 meters; the well was linked to existing production facilities; e) onshore Meleiha permit (Eni’s interest 56%) the Lotus North 1-X discovery well showed the presence of oil at a depth of over 2,000 meters and has started to produce.
The Nada Ne 1-X discovery well showed the presence of oil and natural gas at a depth of 1,900 meters in the same area and has started to produce.
Development activities are underway in the offshore area of the Nile Delta: (i) in the North Port Said concession (Eni’s interest 100%), the Anshuga gas field was linked to the production facilities of the nearby Nouras field by means of a sea line, starting production

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in October 2006. Peak production is expected at 17.7 mmcf/d net to Eni. This and other ongoing development activities aim at maintaining the current gas production level of 459 mmcf/d net to Eni; (ii) in the Ras el Barr concession (Eni’s interest 50%), engineering activities are underway for the development of gas reserves in the offshore Taurt field. This project provides for the drilling of seven wells which are expected to be linked to existing onshore treatment facilities. Production is expected to start in 2008.
A second development step of the Ha’py field was completed. Ongoing development activities aim at maintaining the current gas production level of 177 mmcf/d net to Eni; (iii) in the el Temsah concession (Eni operator with a 50% interest), gas and condensates production started at the Temsah NW 2 platform. Ongoing development activities aim at reaching peak production of 111 kboe/d (33 net to Eni) in 2008. Main projects include the development of reserves at the Denise field and its satellites through existing facilities at Denise A installed on the TNW 2 platform.

As part of the expansion plan of the Damietta LNG plant, Eni and its partners signed a framework agreement in June 2006 for doubling the capacity of the Damietta liquefaction plant by means of the construction of a second train with a treatment capacity of 268 bcf/y of gas corresponding to approximately 5 mmtonnes/y of LNG for a twenty-year period starting in 2010. This project is expected to support the ramp-up of Eni’s natural gas production in the Nile Delta, targeting supplies of 88 bcf/y.
Eni is currently supplying 53 bcf/y to the first train for a twenty-year period.

Libya Main discoveries for the year were in: a) offshore Block NC 41, the T1 discovery well showed the presence of oil at a depth of 2,800 meters; b) onshore concession 82-10 (Eni’s interest 50%), the KK4-82/ST3 discovery well showed the presence of oil at a depth of 5,000 meters.
As part of the Western Libyan Gas project (Eni’s interest 50%), less than one year after the start-up of the
 

offshore Bahr Essalam field located in the NC-41 permit, drilling activity was completed with 26 production wells linked to the Sabratha platform. Production from Bahr Essalam and Wafa fields is processed at the onshore Mellitah plant on three trains fully operational in 2006. Export of natural gas leverages on the GreenStream gasline, delivering 240 bcf in 2006. This gasline is expected to become fully operational in 2007, exporting some 283 bcf (equal to 77 mmcf/d) supplied to third parties on the Italian natural gas market under long term contracts. In addition, 71 bcf of production gas per year will be sold on the Libyan market. The El Feel field (Eni’s interest 33%) reached peak production at 150 kbbl/d supported by available processing capacity at the Mellitah plant.
As part of development activities in the Bouri Est Area, four producing wells were successfully drilled and linked to existing facilities.

Mali In November 2006, Eni purchased five onshore exploration licenses (Eni operator with a 50% interest) from the companies Baraka Mali Operations Limited and Baraka Mali Ventures Limited, covering a gross acreage of 193,000 square kilometers. Blocks are located in the central part of the Taodueni Basin, a completely unexplored and high potential basin according to recent studies. The life span of this exploration license was fixed at four years.
In March 2007, this operation was approved by Malian Authorities.

Tunisia Main discoveries for the year were in: a) Larish concession (Eni’s interest 50%), the Larish SE-1 well found oil at a depth of about 3,000 meters and was linked to existing production facilities; b) Adam concession (Eni operator with a 25% interest), the Karma-1 well showed an oil formation at a depth of 3,617 meters, which confirmed it as a high potential basin; c) in Bordj el Kadra concession (Eni operator with a 50% interest), the Nakhil-1 discovery well showed the presence of high quality oil at a depth of approximately 4,000 meters.

 

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WEST AFRICA
Angola Main discoveries for the year were in: a) the development concessions deriving from former Block 15 (Eni’s interest 20%), the Tchihumba 2 appraisal well confirmed the presence of oil at a depth of about 3,000 meters; b) Block 14K/A IMI unit (Eni’s interest 11.5%), where the Lianzi discovery was made, appraisal activities conducted in the area confirmed the presence of hydrocarbon layers at a depth over 3,000 meters; c) offshore Block 14 (Eni’s interest 20%), the Lucapa 1 discovery well found oil and natural gas at a depth of about 1,200 meters.
In May 2006, following an international bid procedure, Eni was awarded the role of operator in the exploration license of offshore Block 15/06 (Eni’s interest 35%).
This Block is located in an area with great exploration potential, covering a gross acreage of approximately 3,000 square kilometers. The exploration plan envisages drilling of eight wells during a five-year period and an option for extending the license period over a further three-year period and the drilling of three additional wells. In November 2006, Eni signed the relevant Production Sharing Contract (PSC) with the State oil company Sonangol.
In 2006, production started at Benguela/Belize and Lobito/Tomboco fields in Block 14 (Eni’s interest 20%), in January and June, respectively. Joint development of these fields was performed by installing a compliant piled tower provided with treatment facilities for Benguela/Belize and an underwater connection to this tower for Lobito/Tomboco. Peak production at 158 kbbl/d (20 net to Eni) is expected in 2009 upon completion of the drilling program.

Development of the Banzala oil field in Block 0 in Cabinda (Eni’s interest 9.8%) moved forward with the installation of a production platform and drilling of producing and water injection wells. Production is expected to start in the first quarter of 2007 and to peak at 27 kbbl/d (3 net to Eni) in 2009.
An intense campaign to develop reserves in Block 15 (Eni’s interest 20%) is underway: (i) in March 2006, development of the Mondo and Saxi/Batuque oil fields started as part of Phase C of the development of reserves in the Kizomba deep offshore area. A common development strategy is expected to be deployed in both projects, envisaging the installation of an FPSO vessel. Production is expected to start in the first quarter and in second quarter of 2008, respectively. Peak production at 100 kbbl/d (18 net to Eni) is expected in both projects in 2009; (ii) in December 2006, development of the Marimba oil field started with the drilling of producing wells which will be connected to existing facilities
 


in Kizomba A. Peak production is expected in 2008 at 39 kboe/d (7 net to Eni).
Development activities at the Landana and Tombua oil fields in Block 14 offshore (Eni’s interest 20%) progressed with the drilling of producing wells, one of which has already been started up in June 2006. A few production wells, one of which was started-up in June 2006 shall be linked to existing facilities at Benguele/Belize-Lobito/Tomboco. Peak production at 130 kbbl/d (22 net to Eni) is expected in 2010.

Congo A discovery was made in the Mer Très Profond Sud permit (Eni’s interest 30%) with the Aurige Nord Marine – one well yielding 5 kbbl/d of oil in test production.
In February 2007, Eni acquired certain onshore exploration and production assets operated by Maurel & Prom, entailing a cash consideration of $1,434 million. This transaction includes the producing fields of M’Boundi (48.6%) and Kouakouala A (66.7%), the production concession of Kouakouala B (50%) as well as most of the interests in the Le Kouilou (50%) exploration permit which are subject to a pre-emption right in favor of Burren Energy, partner of Maurel & Prom. Eni and Burren Energy reached an agreement providing for Burren Energy's waiver of the exercise of its pre-emption right and Eni's divestiture to the English oil company of a 5.5% interest in the M'Boundi concession and a 2% stake in the Le Kouilou exploration permit under the same economic terms as the acquisition from Maurel & Prom, for an amount of $154 million. Eni retains the operatorship and participating interests of 43.1% and 48% in the M'Boundi concession and Le Kouilou exploration permit, respectively.

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Nigeria: Drilling unit

 

The transaction is subject to approval by the Congolese authorities.
In May 2006, Eni signed a Protocole d’Accord to exploit natural gas reserves in the Marine XII permit, in order to ensure supplies to a power station.
In February 2007, Eni signed an agreement providing for a swap of interests in exploration blocks located in India and in Congo. Within this agreement, Eni acquired a 34% interest in the MN-DWN-2002/1 block, located off the coast of Eastern India, covering an acreage of approximately 10,000 square kilometers at a maximum water depth of over 2,000 meters. The MN-DWN-2002/1 block lies in a high mineral potential basin where significant oil and gas discoveries have already been made. Eni’s partner in this initiative (ONGC Videsh, an Indian oil company) acquired a 20% interest in the Mer Très Profonde Nord exploration block (Eni operator with a 60% interest), located off the coast of Congo from Eni. In June 2006, the offshore Litanzi field (Eni’s interest 35%) started production, peaking at 4 kboe/d (1.4 net to Eni).
Development activities at the Awa Palouku and Ikalou-Ikalou Sud field are underway. Production is expected to start in 2008 peaking at 13 kboe/d net to Eni in 2009.

Nigeria Several successful appraisal wells were drilled in the year: a) in OML 118 offshore block (Eni’s interest 12.5%) with the Bonga North 2 well, drilled at a depth of 3,560 meters; b) in OML 120 offshore block (Eni’s interest 40%) with the Oyo 2 Dir well, drilled at a depth of 1,700 meters; c) in OPL 219 block (Eni’s interest 12.5%), with the Bolia 4 well drilled at a depth of 3,600 meters; d) in the OML 28 (Eni’s interest 5%) with the Kolo Creek 39 well.
 

The Forcados/Yokri oil and gas fields (Eni’s interest 5%) are currently under development offshore and onshore the Niger Delta. Development is expected to be completed in 2007 as a part of the integrated project aiming at providing natural gas supplies to the Bonny liquefaction plant. Offshore production facilities have been installed. The onshore project provides for the upgrading of the Okri and North/South Bank flowstations and the realization of a gas compressor plant.

Eni holds a 10.4% interest in the Bonny liquefaction plant located in the eastern Niger Delta. In 2006, the fifth train started operations, increasing plant capacity to 17 mmtonnes/y of LNG (812 bcf/y of natural gas feedstock). A sixth train with production capacity of 4.1 mmtonnes/y is under construction with start-up expected in 2008; the seventh unit is being engineered. When fully operational total capacity will hit approximately 30 mmtonnes/y, corresponding to a feedstock of 1,448 bcf/y. Development initiatives for ensuring natural gas supplies to the plant regard Blocks OML 60, 61, 62 and 63 (Eni’s interest 20%). When the 6-train plant is fully operational, Eni is expected to supply 268 mmcf/d of equity gas (47 kboe/d), of these 169 mmcf/d (30 kboe/d) from Eni’s interest in NAOC JV and 99 mmcf/d (17 kboe/d) from Eni’s interest in SPDC JV. Engineering activities to build a new LNG plant in Brass, with liquefaction capacity of 10 mmtonnes/y on two trains, are underway. In September 2006, Eni signed a Shareholder Agreement with the partners of this project. Project sanction is expected in 2008, with start-up expected in 2011. Supplies to the plant will come from associated upstream projects targeting 50% of gas feedstock requiremets.

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North Sea: Saipem 7000

 

In March 2007, Eni obtained the role of operator with a 48% interest in the OPL 135 permit. The exploration plan envisages research for and development of oil and natural gas reserves in the proximity of existing facilities and the Kwale/Okpai power station where Eni is operator.

NORTH SEA
Norway Main discoveries for the year were: a) in the Prospecting License 229 (Eni operator with a 65% interest), three appraisal wells of the Goliath discovery confirmed the presence of hydrocarbons at a depth between 1,017 and 1,853 meters; b) in the Prospecting License 128 (Eni’s interest 11.5%), a gas formation was discovered at a depth of 3,000 meters; c) in the Prospecting License 134 (Eni’s interest 30%), an appraisal well of the Morvin discovery confirmed the presence of oil at a depth between 4,600 and 4,900 meters.
In February 2006, following an international bid procedure, Eni was awarded offshore Block 6607/11-122D (Eni’s interest 20%) in the Halten Terrace basin, near the Maruk discovery (Eni operator with a 20% interest,) covering a gross acreage of 7 square kilometers.
In March 2006, following an international bid procedure, Eni was awarded offshore Blocks 7124/6, 7125/4 and 5 in the Prospecting License 393 (Eni’s interest 30%), covering a gross acreage of 525 square kilometers, in the Barents Sea. Exploration plans envisage the drilling of a well in the first three years of the license.
In September 2006, Eni purchased further interests in two exploration licenses off the coast of Norway: (i) in the Prospecting License 221 (Eni’s interest 30%) where the Victoria gas discovery is located, representing a technological challenge due to the high pressure and
 

high temperature conditions of the reservoir; (ii) in the Prospecting License 264 (Eni’s interest 40%) where the Hvitveis gas discovery is located.
In January 2007, following an international bid procedure, Eni was awarded offshore Block 6506/9-6507/7 (Eni’s interest 30%).
Ongoing development activities are focused primarily on hydrocarbon bearing structures located near the Kristin field (Eni’s interest 8.25%). Development of the Tyrihans field (Eni’s interest 6.23%) is expected to be profitable through synergies with the Kristin production facilities. In July, the development plan was sanctioned; relevant contracts for building infrastructure and production facilities are being awarded. Production is expected to start in 2009, in coincidence with the expected production decline of Kristin which will make spare capacity available to process production from Tyrihans.

United Kingdom Main discoveries for the year were in: a) the P/011 permit in Block 30/06a (Eni’s interest 33%) in the central section of the North Sea an appraisal well was drilled at a depth between 4,500 and 5,100 meters confirming the presence of hydrocarbons; b) the P/672 permit in Block 30/02c (Eni’s interest 7%) in the central section of the North Sea, a discovery of a natural gas and condensate bearing layer was made at a depth of 5,000 meters; this well was linked to the production facilities of the nearby Jade field (Eni’s interest 7%).
In March 2006, production started at the offshore gas and condensate Glenelg field (Eni’s interest 8%), developed by means of the facilities of the nearby Elgin Franklin production platform (Eni’s interest 21.87%). In 2006 production totaled 12 kboe/d (1 net to Eni).
Development activities are nearing completion at the Blane field in Block 30/3a (Eni’s interest 18%).

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United States (Gulf of Mexico): The Allegheny production platform

Production at 12 kboe/d (2.2 net to Eni) is expected to start in the first half of 2007.

REST OF WORLD
Australia In offshore Block WA-25-L (Eni operator with a 65% interest), the Woollybutt-5 appraisal well confirmed the presence of oil at a depth of 2,865 meters.
In June 2006, development started at the offshore Blacktip gas and liquids field (Eni’s interest 100%) located in the WA-279-P Block at a water depth of 50 meters in the Bonaparte basin, south of the Australian coast. This project envisages the installation of a production platform approximately 100 kilometers from the mainland and construction of an onshore treatment plant with a capacity of 46 bcf/y. Start-up is expected in January 2009. Under a 25-year agreement signed with the Darwin Power & Water Utility Co, a total amount of 706 bcf of natural gas is expected to be supplied with an option for further volume increases.
In February 2006, the first shipment of LNG was delivered to two Japanese operators from the Darwin liquefaction plant with a capacity of 3.5 mmtonnes/y of LNG (equivalent to approximately 173 bcf/y of natural gas). This plant is linked by means of a 500-kilometer long pipeline to the liquids and gas Bayu Undan field located at a water depth of 80 meters in permits JPDA 03-12 and JPDA 03-13 in the waters of the international cooperation zone between Australia and East Timor (Eni’s interest 12.04%).

Brazil In January 2006, following an international bid procedure, Eni was awarded a six-year exploration license in Block BM Cal-14, acting as operator. Gross acreage extends over approximately 700 square kilometers in the deep waters of the Camamu-Almada basin.
In November 2006, following an international bid,
 

Eni was awarded offshore Block S-M-857 (Eni’s interest 100%), covering a gross acreage of 700 square kilometers, in the deep waters of the Santos basin. The assignation of blocks has not yet been completed.

Croatia In the offshore Ivana concession (Eni’s interest 50%) the Ana 1 and Vesna 1 discovery wells identified the presence of natural gas at a depth between 650 and 1,200 meters.
Ivana C/K platforms and Ika and Ida fields started production as part of the development of the natural gas reserves of the Ivana concession. Production from these fields is gathered at the Ivana K platform from which is sent to the Garibaldi K platform to be sold on the Italian market, through a 67-kilometer long pipeline. Production from these four fields is currently flowing at 152 mmcf/d (49 net to Eni). At the end of 2006, production at the Katarina field started by means of two platforms linked to existing transport facilities.

East Timor In May 2006 following an international bid procedure Eni was awarded the operatorship of five exploration licenses (Eni’s interest 100%) covering contract areas A, B, C, E and H with a gross acreage of about 12,183 square kilometers located in the deep offshore between the Timor island and the international cooperation zone between East Timor and Australia. Relevant Production Sharing contracts were signed.

Kazakhstan Eni is single operator with an 18.52% interest of the North Caspian Sea PSA. Such contract regulates activity in the relevant contractual area where the Kashagan field was discovered, which is deemed to be the most important discovery in the world in the past thirty years. The development plan of this field was sanctioned in February 2004, entailing a three-phase development scheme to produce from 7 to 9 bbbl of recoverable reserves, extendable to 13 bbbl through partial gas reinjection.

The first development phase is progressing leveraging on the use of the most advanced techniques in order to cope with high pressures in the reservoir, the presence of high concentration of hydrogen sulphide and harsh environmental conditions. By the end of 2006, works had been completed corresponding to 59% of the initial scope, with the total amount of contracts awarded at $10.6 billion. Drilling activities and completion of development wells from the two artificial islands already installed have been progressing. In addition, three rigs, two of which being of the most advanced class, were installed on said islands. Three development wells were completed yielding high rates of productivity under test phase.
Production start-up is currently scheduled for the third quarter of 2010 as compared to an initial forecast

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indicating a start-up in 2008, due also to the need on part of Eni to perform certain studies to define measures intended to enhance the overall level of safety and operability of facilities. As a result of said reconfiguration completed by year-end, the onshore design has been confirmed, while certain enhancements have been identified offshore which do not alter the original development concept. These enhancements are expected to be included in the development plan and implemented. Estimated capital expenditure to reach the 300 kbbl/d production target in first development phase stands currently at $19 billion, representing a remarkable increase over the approved budget of $10.3 billion in real terms 2007, sanctioned in 2004. This cost increase was driven by: (i) a cost increase of materials and services driven by sector-specific inflation and a negative impact due to a weakening US dollar; (ii) an underestimation of costs to conduct offshore operations in shallow/ultra shallow waters where the Kashagan field is located due to a lack of benchmarks, also reflecting technical and logistic issues and environmental constraints; (iii) the enhancements to the original layout of offshore facilities. Based on the high level of productivity yielded by the first three development wells, management currently expects a full field production plateau of 1.5 mmbl/d, representing a 25% increase from the original target envisaged by the development plan.
Evaluation activities of the discoveries made in the contractual area covered by the North Caspian Sea PSA made some good progress. A first appraisal well of the Kairan discovery was successfully drilled. Drilling of a second appraisal well of the Kalamkas discovery yielded productive results that emphasize the good productivity of the reservoir and a much larger extension of said discovery as compared to the initial estimate.
At the Karachaganak field (Eni co-operator with a 32.5% interest), good well performance and high yields of gas treatment and injection plants allowed: (i) to ship an average of 43,900 bbl/d net to Eni to the terminal of the North Caspian Pipeline Consortium at Novorossiysk on the Black Sea; (ii) to sell approximately 78 bcf of natural gas, net to Eni, in Russia.
In July 2006, a first cargo of oil was delivered to Odessa and Primorsk via the Atyrau-Samara pipeline, marking the start-up of the Baltic route for the export of production to Western markets.
Maintenance activities have been continuing targeting the support of the current liquid production plateau. During the year, new wells were drilled and an upgrading of liquid treatment facilities was sanctioned envisaging the construction of a fourth unit. Such new capacity is expected to increase export of production volumes
 

which were previously marketed on local Russian markets, resulting in an enhancement of prices realizations.

Mozambique In March 2006, following an international bid tender, Eni obtained the exploration license for Area 4, located in the deep offshore of the Rovuma Basin. This block covers a gross area of 17,646 square kilometers in an unexplored geological basin with great mineral potential according to surveys performed. In December 2006, Eni signed the relevant exploration contract.

Pakistan In February 2006, following an international bid procedure, Eni was awarded the operatorship of four exploration licenses relating to Block Rjar/Mithi - zone I and Thar/Umarkot - zone III. These blocks are located in the East Sindh near the border with India and cover a gross area of about 9,900 square kilometers.
In March 2006, an expansion plan of the Bhit and Badhra operated permits was sanctioned, envisaging the construction of a third train for increasing treatment capacity of the Bhit plant also enabling to process Badhra field gas production. In the Zamzama field construction of a new treatment plant is underway.

United States - Gulf of Mexico Main discoveries for the year were: a) in Mississippi Canyon Block 546 (Eni’s interest 50%), the Longhorn appraisal well confirmed the presence of natural gas at a depth of about 3,900 meters; b) in Mississippi Canyon Block 502 (Eni’s interest 100%), the Longhorn North discovery well showed the presence of natural gas at a depth of 3,400 meters. A feasibility study to develop this discovery is underway.
The Allengheny South (Eni’s interest 100%) and North Black Widow (Eni’s interest 25.19%) fields started production as part of activities to develop reserves in the Gulf of Mexico.

United States - Alaska In November 2006, Eni started an exploration campaign in the onshore Rock Flour area (Eni’s interest 100%). The approved plan provides for the drilling of three wells.
In March 2006, following an international bid procedure, Eni was awarded 11 exploration blocks near Rock Flour.
Eni signed an agreement with a partner for a swap of interests in 64 exploration blocks (Eni’s interest 60%) located in the Beaufort Sea, offshore North Alaska. Based on this agreement, Eni is entitled to 140 exploration blocks (50% of which operated). Exploration plans provide for 3D seismic surveys and drilling of an exploration well by 2010.

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United States (Gulf of Mexico): The Allegheny production platform

 

In January 2006, the development plan of the offshore Oooguruk field in the Beaufort Sea started. Production is expected to start at the end of 2007 with production peaking at 17 kboe/d (over 5 net to Eni) in 2010. Drilling activities in Nikaitchuq field (Eni’s interest 30%), located in the Beaufort Sea, are underway.

Turkey In June 2006, construction licenses for the Samsun-Ceyhan pipeline were assigned to the Turkish company Çalik Enerji, partnering Eni in this initiative (both with a 50% stake). This pipeline is expected to bypass the Turkish Straits of Bosphorus and Dardanelles, enabling delivery of oil produced in the Caspian region to the Ceyhan commercial hub on the Mediterranean coast. This new infrastructure will be 550 kilometer long with a maximum transport capacity of 1.5 mmbbl/d of oil, corresponding to approximately 75 mmtonnes/y and will represent a more efficient and environment friendly alternative as compared to the option of transporting oil by ship through the Bosphorus and Dardanelles straits. Construction activities started in second half of 2006.

Venezuela In January 2006, following an international bid procedure, Eni was awarded a thirty year long exploration license for the Cardon IV Block (Eni’s interest 50%) in joint venture with an international oil company. This Block is part of the Rafael Urdaneta project for the development of natural gas reserves in an area of about 30,000 square kilometres in the Gulf of Venezuela.
In May 2006, a first development phase of the Corocoro field in Gulf of Paria West Block (Eni’s interest 26%) started with some drilling work. A second development phase is expected to be designed based on the results achieved in the first one as regards well production rate and field performance under water and gas injection.
 

Production is expected to start in 2007.
With effective date April 1, 2006, the Venezuelan State oil company Petróleos de Venezuela SA (PDVSA) unilaterally terminated the Operating Service Agreement (OSA) governing activities at the Dación oil field where Eni acted as a contractor, holding a 100% working interest. As a consequence, starting on the same day, operations at the Dación oil field are conducted by PDVSA. Eni proposed to PDVSA to agree on terms in order to recover the fair value of its Dación assets. On November 2006, Eni commenced a proceeding before the International Centre for Settlement of Investment Disputes (ICSID) Tribunal (i.e. a tribunal acting under the auspices of the ICSID Convention and being competent pursuant to the Treaty) to claim its rights. In fact, a bilateral investments treaty is in place between the Netherlands and Venezuela (the “Treaty”). Despite this action, Eni is still ready to negotiate a solution with PDVSA to obtain a fair compensation for its assets. Based on the opinion of its legal consultants, Eni believes to be entitled to a compensation for such expropriation in an amount equal to the market value of the OSA before the expropriation took place. The market value of the OSA depends upon its expected profits. In accordance with established international practice, Eni has calculated the OSA’s market value using the discounted cash flow method, based on Eni’s interest in the expected future hydrocarbon production and associated capital expenditures and operating costs, and applying to the projected cash flow a discount rate reflecting Eni’s cost of capital as well as the specific risk of concerned activities. Independent evaluations carried out by a primary petroleum consulting firm fully support Eni’s internal evaluation. The estimated net present value

 

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of Eni’s interest in the Dación field, as calculated by Eni, is higher than the net book value of the Dación assets which consequently have not been impaired. In accordance with the ICSID Convention, a judgement by the ICSID Tribunal awarding compensation to Eni would be binding upon the parties and immediately enforceable as if it were a final judgement of a court of each of the States that have ratified the ICSID Convention. The ICSID Convention was ratified in 143 States. Accordingly, if Venezuela fails to comply with the award and to pay the compensation, Eni could take steps to enforce the award against commercial assets of the Venezuelan Government almost anywhere those may be located (subject to national law provisions on sovereign immunity). In 2005 and in the first quarter of 2006, oil production from the Dación field averaged approximately 60 kbbl/d and booked reserves at December 31, 2005 amounted to 175 mmbbl.
On February 26, 2007, the President of Venezuela enacted a decree providing for the transformation of certain strategic partnerships operating in the petroleum region of Orinoco (Faja) and certain agreements to conduct risk shared exploration activities into a regime of “empresa mixta” within six months from publication of said decree. Under the new regime, a company incorporated under the law of Venezuela is expected to be entitled to relevant mineral rights and to conduct petroleum operations. A stake of at least 60% in the capital of such company is expected to be held by an affiliate of PDVSA, preferably Corporación Venezuelana de Petróleo. Such decree could impact Eni’s activities in Venezuela, as Eni’ s subsidiary Eni Venezuela
 

BV holds a stake in a joint venture operating the Gulf of Paria West Block, located in the Orinoco delta as outlined above. However, management is currently unable to assess such impact, as terms and conditions regulating the participation of foreign companies to an “empresa mixta” have not yet been agreed upon.

Italy
Main gas discoveries for the year were made in: a) the onshore San Polito concession in Emilia, the Longanesi 1 well, at a depth of 2,540 meters; b) the offshore of Sicily (GR.13.AG permit, Argo 1 well, Eni’s interest 60%) at a depth between 1,350 and 1,520 meters; c) the Adriatic Sea (AR.95.EA permit, Benedetta 1 well) at a depth of 2,090 meters which yielded 145 kcm/d of gas in test production; d) the onshore of Sicily (San Teodoro permit, Borgo Giuliano 1 well) at a depth of about 2,000 meters.
Development activities concerned in particular: (i) optimization of producing fields by means of sidetracking and infilling (Barbara A/H, Daria, Basil and Anemone for gas and Rospo for oil); (ii) continuation of drilling and upgrading of producing facilities in the Val d’Agri. The main oil reserves development project is Miglianico, located onshore in the Abruzzi Region. Production is expected to start in the second half of 2008. This project provides for the construction of facilities intended to treat production volumes of oil, to be delivered to logistic structures of the Refining & Marketing Division, and to desulfurize production volumes of gas to be input into the Italian natural gas transportation network.

 

Capital expenditure  

(million euro)

 

2004

 

2005

 

2006

 

Change

 

% Ch.

       
 
 
 
 
Acquisition of proved and unproved property      

301

 

152

 

(149

)  

(49.5

)
Italy          

139

           
North Africa          

10

           
West Africa      

60

               
Rest of World      

241

 

3

           
Exploration  

499

 

656

 

1,348

 

692

   

105.5

 
Italy  

51

 

38

 

128

 

90

   

..

 
North Africa  

90

 

153

 

270

 

117

   

76.5

 
West Africa  

70

 

75

 

471

 

396

   

..

 
North Sea  

66

 

126

 

174

 

48

   

38.1

 
Rest of World  

222

 

264

 

305

 

41

   

15.5

 
Development  

4,310

 

3,952

 

3,629

 

(323

)  

(8.2

)
Italy  

378

 

411

 

403

 

(8

)  

(1.9

)
North Africa  

1,358

 

1,007

 

701

 

(306

)  

(30.4

)
West Africa  

865

 

889

 

864

 

(25

)  

(2.8

)
North Sea  

338

 

385

 

406

 

21

   

5.5

 
Rest of World  

1,371

 

1,260

 

1,255

 

(5

)  

(0.4

)
Other  

44

 

56

 

74

 

18

   

32.1

 
   

4,853

 

4,965

 

5,203

 

238

   

4.8

 
   
 
 
 

 

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Development of onshore gas fields is nearing completion at: (i) Tea, Arnica, Lavanda in the Adriatic offshore where start-up of production is expected in 2007. In 2006, a production platform and linkage facilities have been installed; (ii) Candela, where start-up is expected in 2007; (iii) certain gas fields in Sicily: Pizzo Tamburino, scheduled for the second half of 2007 with expected production of 0.5 kboe/d, Samperi 1, which started in 2006 with a production peak of approximately 1 kboe/d, and recovery of additional reserves of Fiumetto concession, where start-up is expected in the first half of 2007 peaking at 600 boe/d.

Capital expenditure
In 2006, capital expenditure of the Exploration & Production segment amounted to euro 5,203 million and concerned mainly development expenditure, directed mainly outside Italy, in particular in Kazakhstan, Angola and Egypt. Development expenditure in Italy concerned in particular the continuation of drilling development wells, the completion of work for plant and infrastructure in Val d’Agri and sidetrack and infilling actions in mature areas. Exploration expenditure, of which 90% was directed outside Italy, concerned in particular Angola, Egypt, Norway, Nigeria and the Gulf of Mexico. In Italy exploration concerned essentially the offshore of Sicily, the Po Valley and the Adriatic Sea.
 

As compared to 2005, capital expenditure increased by euro 238 million, up 4.8%, due to the increase in exploration expenditure mainly in Egypt and Nigeria. These effects were offset in part by lower development expenditure resulting essentially from the completion of relevant projects in Libya (Bahr Essalam), Nigeria (trains 4 and 5 of the Bonny LNG plant) and the purchase of an additional 1.85% interest in the Kashagan field in the first half of 2005 (euro 169 million).

Storage
Natural gas storage activities are performed by Stoccaggi Gas Italia SpA (“Stogit”) to which such activity was conferred on October 31, 2001 by Eni SpA and Snam SpA, in compliance with Article 21 of Legislative Decree No. 164 of May 23, 2000, which provided for the separation of storage from other activities in the field of natural gas.
Storage services are provided by Stogit through eight storage fields located in Italy, based on 10 storage concessions vested by the Ministry of Productive Activities.
In 2006, the share of storage capacity used by third parties was 46%. From the beginning of its operations, Stogit markedly increased the number of customers served and the share of revenues from third parties; the latter, from a non significant value, passed to 42%.

 

   

2004

 

2005

 

2006

   
 
 
Available capacity                
Modulation and mineral  

(bcm)

 

7.5

 

7.5

 

8.4

- share utilized by Eni  

(%)

 

47

 

44

 

54

Strategic  

(bcm)

 

5.1

 

5.1

 

5.1

Total customers  

(units)

 

39

 

44

 

38

Customers of modulation and mineral services  

(units)

 

29

 

35

 

38

       
 
 

 

Regulatory framework
Storage code
With Resolution No. 220/06, the Italian Authority for Electricity and Gas approved the storage code proposed by Stoccaggi Gas Italia on the basis of the framework and criteria established by Resolution No.119/05 (“Adoption of guarantees for free access to natural gas storage services, duties of subjects operating storage activities and rules for the preparation of a storage code”).
This code disciplines access to and provision of storage services during normal operational conditions, regulates procedures for conferring storage capacities,
 

fulfilment of obligations concerning operating programming and fees to be charged to customers.
The code has been in force since November 1, 2006, as of the beginning of the storage cycle.
The storage company offers services, on economic conditions and according to an access priority established by the Italian Authority for Electricity and Gas as follows:
(i) services which the storage company is obliged to offer consisting of: modulation storage services, mineral storage services, and strategic storage services.
(ii) operating balancing services of transport companies, including hourly modulation.

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The modulation storage service is finalized to satisfy daily, seasonal and eloinare demand peak modulation needs. Final clients consuming less than 200,000 cm on an annual basis are entitled to a priority when satisfying their modulation requirements. To that end, the storage company makes available its capacity for space, injection and offtake on an annual basis in accordance with its storage code.
The mineral storage service is finalized to allow natural gas producers to perform their activity under optimal operating conditions, according to criteria determined by the Ministry of Economic Development.
The strategic storage service is destined to satisfy certain obligations of natural gas importers from countries not belonging to the EU in accordance with Art. 3 of Legistlative Decree No. 164/2000. The relevant storage capacity dedicated to this service is determined by the Ministry of Economic Development.

Determination of tariffs
According to Resolution No. 50/06 of the Italian Authority for Electricity and Gas (“Criteria for the determination of tariffs for natural gas storage services”), the storage company calculates revenues for the determination of unit tariffs for storage services by adding the following cost elements:
i) a return on the capital employed by the storage company equal to 7.1% (8.33% in the first regulated period). The Resolution confirmed the mechanisms for the evaluation of net capital employed established in the prior regulatory period;
ii) technical and economic depreciation charges;
iii) operating costs.
 

In the years following the first year of the new regulated period, reference revenues are updated to take account of variations of capital employed and the impact of the indexation of depreciation charges and operating costs to consumer price inflation lowered by a preset rate of productivity recovery.
Storage tariffs are articulated as follows:
i) a unit fee for the use of space;
ii) a unit fee for the use of injection capacity;
iii) a unit fee for the use of offtake capacity;
iv) a unit fee for gas volumes handling;
v) a unit fee for having such volumes of gas available as necessary to fulfil strategic storage obligations on part of interested operators.

Applicable regulation provides for incentives to capital expenditure intended to develop and upgrade storage capacity by recognizing an additional rate of return of 4% on the basic rate to capital expenditure projects aiming at developing new storage deposits and increasing existing capacity. Such incentives are applicable for a sixteen-year period and an eight-year period, respectively.

Fees charged for balancing activities
and storage restoration

Fees deriving from balancing activities and restoration of strategic volumes offtaken are regulated by certain prescriptions from the Italian Authority for Electricity and Gas providing for repartition of such fees among customers of storage services until the 2005-2006 thermal year.
Resolution No. 50/2006 changed such regime by establishing that such fees cover revenues deriving from new investment.

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Gas & Power

 

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

17,302

 

22,969

 

28,368

Operating profit      

3,428

 

3,321

 

3,802

Adjusted operating profit      

3,448

 

3,531

 

3,882

Adjusted net profit      

2,290

 

2,552

 

2,862

Capital expenditure      

1,451

 

1,152

 

1,174

Adjusted capital employed, net      

18,383

 

18,898

 

18,864

ROACE adjusted  

(%)

 

12.6

 

13.7

 

15.1

Worldwide gas sales  

(bcm)

 

87.03

 

94.21

 

97.48

Total gas sales in Europe      

85.32

 

92.50

 

95.97

- G&P division sales      

80.62

 

87.99

 

91.90

- Upstream sales (b)      

4.70

 

4.51

 

4.07

Customers in Italy  

(million units)

 

5.95

 

6.02

 

6.54

Gas volumes transported in Italy  

(bcm)

 

80.41

 

85.10

 

87.99

Electricity production sold  

(terawatthour)

 

13.85

 

22.77

 

24.82

Employees at year end  

(units)

 

12,843

 

12,324

 

12,074

       
 
 
     
(a)   Before elimination of intersegment sales.
(b)   Does not included Eni’s share of sales made by Nigeria LNG (Eni’s share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006 respectively.

Strategic agreement with Gazprom
› In November 2006, Eni and Gazprom signed a broad strategic agreement. This agreement strengthens a long term partnership between the two companies and represents a fundamental step towards the security of energy supplies to Italy. Key features of this deal are the extension of the duration of Gazprom gas supply contracts to Eni until 2035, further strengthening Eni’s supply portfolio and the pursuing of joint initiatives in the upstream sector. Gazprom is expected to enter the Italian market by selling volumes of gas starting in 2007. Gazprom will obtain the availability of such volumes by means of a corresponding reduction in volumes previously supplied to Eni

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Financial results
› The Gas & Power business confirmed its ability to generate strong and stable performances. The adjusted net profit rose euro 310 million to euro 2,862 million compared to 2005 (up 12.1%) reflecting primarily higher selling margins on natural gas sales, a lower impact of Resolution No. 248/2004 of the Italian Authority for Electricity and Gas, a growth in natural gas volumes sold, volumes transported for the coming on line of the GreenStream gasline and electricity production sold

› Return on average capital employed was 15.1% on an adjusted basis in 2006 (13.7% in 2005)

› Capital expenditure totalled euro 1,174 million and related essentially to development and maintenance of Eni’s transport and distribution networks in Italy, the finalization of the upgrading plan of electricity generation capacity and the start up of the upgrading plan of import gaslines

Operating results
› Natural gas sales were up approximately 4% to 97.48 bcm primarily reflecting a growth in sales in a number of target European markets (up approximately 16% in particular in Turkey, Germany/Austria, France) also for the build-up of supplies of natural gas from Libya, partly offset by a decrease in sales in Italy due to mild weather conditions in the fourth quarter of the year

› Electricity production sold was 24.82 terawatthour, up 9% compared with 2005 reflecting the ramp-up of new production capacity

Other developments
› As a part of its development strategy of the natural gas distribution and sale businesses by means of regional alliances, Eni and its local authority partners defined the Toscana project with the establishment of a regional distribution company, managed by Eni and boasting 1.6 million users and a regional selling company controlled by Eni boasting 600 thousand clients and 1.1 billion cubic meters of annual sales

 

NATURAL GAS

Supply of natural gas
In 2006, Eni’s Gas & Power segment supplied 89.27 bcm of natural gas, with an increase of 6.71 bcm from 2005, up 8.1%. Natural gas volumes supplied outside Italy (79.06 bcm) represented 89% of total supplies of fully consolidated subsidiaries (87% in 2005) with a 7.23 bcm increase from 2005 (up 10.1%), primarily reflecting the reaching of full volumes of supplies from Libyan fields (up 2.79 bcm), higher purchases from the Netherlands (up 1.99 bcm), from Russia to the Turkish market (up 1.21 bcm) and via LNG (1.01 bcm). In addition, supplies from Croatia increased (up 0.43 bcm) due to the ramp-up of new production from Eni-operated natural gas fields in the Adriatic offshore. The main declines concerned purchases from Algeria (down 0.74 bcm) and extra Europe supplies. Supplies in Italy (10.21 bcm) declined by 0.52 bcm, down 4.8%, from 2005, due to a production decline of Eni’s natural gas fields.
 

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In 2006, natural gas volumes input to storage deposits owned by Stoccaggi Gas in Italy and Gaz de France in French territory and in Austria were 3.01 bcm, compared to net offtakes of 0.84 bcm in 2005.

TAKE-OR-PAY
In order to meet the medium and long-term demand for natural gas, in particular in the Italian market, Eni entered into long-term purchase contracts with producing countries. Specifically, following the strategic agreement with Gazprom signed on November 14, 2006, effective from February 1, 2007, Eni extended the duration of its gas supply contracts with Gazprom until 2035, bringing the residual average life of its supply portfolio to approximately 23 years. Existing contracts, which in general contain take-or-pay clauses, will ensure a total of approximately 62.4 bcm/y of natural gas by 2010.
Despite the fact that an increasing portion of natural gas volumes purchased under said contracts has been sold outside Italy, management believes that in the long term unfavorable trends in the Italian demand and supply for natural gas, also due to the possible implementation of all publicly announced plans for the construction of new supply infrastructure, and
  the evolution of Italian regulations of the natural gas sector, represent risk factors to the fulfilment of Eni’s obligations in connection with its take-or-pay supply contracts.

Sales of natural gas
Natural gas sales (97.48 bcm, including own consumption, Eni’s share of affiliates sales and upstream sales in Europe) were up 3.27 bcm from 2005, or about 4%, due to higher sales in the rest of Europe (4.9 bcm, up approximately 16%), higher supplies of natural gas to Eni’s wholly-owned subsidiary EniPower for power generation (up 0.59 bcm, or 10.6%), offset in part by lower sales by fully consolidated subsidiaries in Italy (down 1.53 bcm, or 2.9%).
In an increasingly competitive market, natural gas sales of fully consolidated subsidiaries in Italy (50.94 bcm) declined by 1.53 bcm from 2005, due to lower supplies related to mild weather conditions in the fourth quarter, negatively affecting sales volumes to the power generation segment (down 0.93 bcm), wholesalers (down 0.51 bcm) and residential and commercial users (down 0.4 bcm) , offset in part by higher sales to the industrial sector (up 0.26 bcm). Sales under the so-called gas release1 (2 bcm) increased by 0.05 bcm from 2005.

     
(1)   In June 2004 Eni agreed with the Antitrust Authority to sell a total volume of 9.2 bcm of natural gas (2.3 bcm) in the four thermal years from October 1, 2004 to September 30, 2008 at the Tarvisio entry point into the Italian network.

 

Supply of natural gas   (bcm)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Italy  

11.30

   

10.73

   

10.21

   

(0.52

)  

(4.8

)
Russia for Italy  

20.62

   

21.03

   

21.3

   

0.27

   

1.3

 
Russia for Turkey  

1.60

   

2.47

   

3.68

   

1.21

   

49.0

 
Algeria  

18.86

   

19.58

   

18.84

   

(0.74

)  

(3.8

)
Netherlands  

8.45

   

8.29

   

10.28

   

1.99

   

24.0

 
Norway  

5.74

   

5.78

   

5.92

   

0.14

   

2.4

 
Hungary  

3.56

   

3.63

   

3.28

   

(0.35

)  

(9.6

)
Libya  

0.55

   

3.84

   

6.63

   

2.79

   

72.7

 
Croatia  

0.35

   

0.43

   

0.86

   

0.43

   

100.0

 
United Kingdom  

1.76

   

2.28

   

2.5

   

0.22

   

9.6

 
Algeria (LNG)  

1.27

   

1.45

   

1.58

   

0.13

   

9.0

 
Others (LNG)  

0.70

   

0.69

   

1.57

   

0.88

   

..

 
Other supplies Europe  

0.12

   

1.18

   

1.85

   

0.67

   

56.8

 
Outside Europe  

1.21

   

1.18

   

0.77

   

(0.41

)  

(34.7

)
Outside Italy  

64.79

   

71.83

   

79.06

   

7.23

   

10.1

 
Total supplies  

76.09

   

82.56

   

89.27

   

6.71

   

8.1

 
Offtake from (input to) storage  

0.93

   

0.84

   

(3.01

)  

(3.85

)  

..

 
Network losses and measurement differences  

(0.53

)  

(0.78

)  

(0.50

)  

0.28

   

(35.9

)
Available for sale of Eni's own companies  

76.49

   

82.62

   

85.76

   

3.14

   

3.8

 
Available for sale of Eni's affiliates  

5.84

   

7.08

   

7.65

   

0.57

   

8.1

 
Total available for sale  

82.33

   

89.70

   

93.41

   

3.71

   

4.1

 
   

 

 

 

 

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Own consumption2 was 6.13 bcm, up 0.59 bcm or 10.6%, reflecting primarily higher supplies to EniPower due to the coming on stream of new generation capacity.
In 2006, natural gas sales of fully consolidated subsidiaries in the rest of Europe increased by 4.49 bcm to 27.93, or 19.2%, reflecting a growth in: (i) sales under long-term supply contracts to Italian importers (up 2.57 bcm) for the progressive reaching of full supplies from Libyan fields; (ii) supplies to the Turkish market (up 1.22 bcm); (iii) Germany and Austria (up 0.84 bcm) essentially due to increased spot sales to Gaz de France and higher supplies to other industrial operators and wholesalers; (iv) France (up 0.42 bcm) relating to higher supplies to industrial operators. These increases were partly offset by a decrease in sales in Hungary (down 0.29 bcm) and Northern Europe (down 0.1 bcm).
Sales of natural gas by Eni’s affiliates in the rest of Europe, net to Eni and net of Eni’s supplies, amounted to 6.88 bcm, up 0.4 bcm with Unión Fenosa Gas posting the major increase, and concerned: (i) GVS (Eni’s interest 50%) with 2.94 bcm; (ii) Unión Fenosa Gas
 

 
(Eni’s interest 50%) with 2.17 bcm; and (iii) Galp Energia (Eni’s interest 33.34%) with 1.65 bcm.

     
(2)   In accordance with Article 19, paragraph 4 of Legislative Decree No. 164/2000, the volumes of natural gas consumed in operations by a company or its subsidiaries are excluded from the calculation of ceilings for sales to end customers and from volumes input into the Italian network to be sold in Italy.

 

Natural gas sales   (bcm)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Italy (*)  

50.08

   

52.47

   

50.94

   

(1.53

)  

(2.9

)
Wholesalers (selling companies)  

13.87

   

12.05

   

11.54

   

(0.51

)  

(4.2

)
Gas release  

0.54

   

1.95

   

2

   

0.05

   

2.6

 
End customers  

35.67

   

38.47

   

37.40

   

(1.07

)  

(2.8

)
     Industries  

12.39

   

13.07

   

13.33

   

0.26

   

2.0

 
     Power generation  

15.92

   

17.6

   

16.67

   

(0.93

)  

(5.3

)
     Residential  

7.36

   

7.8

   

7.4

   

(0.40

)  

(5.1

)
Own consumption (*)  

3.7

   

5.54

   

6.13

   

0.59

   

10.6

 
Rest of Europe (*)  

21.54

   

23.44

   

27.93

   

4.49

   

19.2

 
Outside Europe  

1.17

   

1.17

   

0.76

   

(0.41

)  

(35.0

)
Total sales to third parties and own consumption  

76.49

   

82.62

   

85.76

   

3.14

   

3.8

 
Sales of natural gas of Eni’s affiliates (net to Eni)  

5.84

   

7.08

   

7.65

   

0.57

   

8.1

 
     Italy (*)        

0.07

   

0.02

   

(0.05

)  

(71.4

)
     Rest of Europe (*)  

5.3

   

6.47

   

6.88

   

0.41

   

6.3

 
     Outside Europe  

0.54

   

0.54

   

0.75

   

0.21

   

38.9

 
Total sales and own consumption (G&P)  

82.33

   

89.7

   

93.41

   

3.71

   

4.1

 
Upstream in Europe (a)  

4.7

   

4.51

   

4.07

   

(0.44

)  

(9.8

)
Worldwide  

87.03

   

94.21

   

97.48

   

3.27

   

3.5

 
Gas sales in Europe  

85.32

   

92.5

   

95.97

   

3.47

   

3.8

 
G&P in Europe (*)  

80.62

   

87.99

   

91.9

   

3.91

   

4.4

 
Upstream in Europe (a)  

4.7

   

4.51

   

4.07

   

(0.44

)  

(9.8

)
   

 

 

 

 

     
(*)   Market sectors denoted with an asterisk are included in "G&P in Europe".
(a)   Does not include Eni's share of sales made by Nigeria LNG (Eni's share 10.4%) in Europe amounting to 1.30, 1.31 and 1.55 bcm in 2004, 2005 and 2006, respectively.

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Unión Fenosa Gas sold 0.45 bcm in international markets, in particular in Japan (0.27 bcm) and South Korea (0.09 bcm), as new market opportunities arose allowing to optimize selling margins.

Transport and regasification of natural gas
In 2006, volumes of natural gas input in the national grid (87.99 bcm) increased by 2.89 bcm from 2005, up 3.4%, primarily reflecting higher volumes input to storage. Eni transported 30.9 bcm of natural gas on behalf of third parties in Italy, up 0.68 bcm from 2005, or 2.3%.
In 2006, the LNG terminal in Panigaglia (La Spezia) regasified 3.13 bcm of natural gas (2.49 bcm in 2005), discharging 96 tanker ships (79 in 2005). The increase
  in volumes regasified reflected a higher availability of LNG on the market.

Development projects
LNG Egypt
Eni, through its interest in Unión Fenosa Gas, owns a 40% stake in the Damietta liquefaction plant producing approximately 5 mmtonnes/y of LNG equal to a feedstock of 7.6 bcm/y of natural gas. In June 2006, the partners of the project (Unión Fenosa Gas, the Spanish-Egyptian company SEGAS an affiliate of Unión Fenosa Gas, State owned Egyptian companies EGAS and EGPC, and oil producers Eni and BP) defined terms and conditions for doubling the plant capacity by means of another treatment train. Expected capital expenditure amounts to

 

Gas volumes transported (a)   (bcm)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Eni  

52.15

   

54.88

   

57.09

   

2.21

   

4.0

 
On behalf of third parties  

28.26

   

30.22

   

30.9

   

0.68

   

2.3

 
Enel  

9.25

   

9.9

   

9.67

   

(0.23

)  

(2.3

)
Edison Gas  

8.00

   

7.78

   

8.8

   

1.02

   

13.1

 
Others  

11.01

   

12.54

   

12.43

   

(0.11

)  

(0.9

)
   

80.41

   

85.1

   

87.99

   

2.89

   

3.4

 
   

 

 

 

 

     
(a)   Include amounts destined to domestic storage.

 

approximately $1.5 billion; start-up is expected by 2010. For further information about the upstream section of the project see “Exploration & Production - Main exploration and development projects”.
The project also foresees the construction of two tankers each with a capacity of 155,000 cm.

LNG Spain
In April 2006, the Sagunto regasification plant with a capacity of 6.7 bcm/y started operations near Valencia. Eni, through Unión Fenosa Gas, holds a 21.25% interest in this plant. At present, Eni’s share of regasification capacity amounts to 1.6 bcm/y of gas. A capacity upgrading plan has been sanctioned targeting a 0.8 bcm/y capacity increase by 2009. Relevant works started in the second half of 2006.
Eni through Unión Fenosa Gas also holds a 9.5% interest in the El Ferrol regasification plant, located in Galicia, under construction and expected to be completed by the first half of 2007, targeting a treatment capacity of approximately 3.6 bcm/y, 0.4 bcm/y being Eni’s share.

Marketing actions in Germany and France
In 2006, Eni began to supply the German company Wingas under a long-term contract, envisaging 1.2
  bcm/y of natural gas. The gas is delivered at Eynatten at the German-Belgian border.
Marketing activities targeting an increase in natural gas sales in Germany and the pursuit of new opportunities arising from the ongoing liberalization process have been started.
In 2006, Eni started direct sales of natural gas in the French market with a new branch in Paris. New industrial and wholesaler clients were acquired; sales for the year hit the 1 bcm level.
Supplies to the French company EDF ramped up, in execution of the long term supply contract signed in July 2005.

Galp
On March 29, 2006, an eight-year agreement among Galp partners became effective addressing the joint management of the company. Galp partners include Eni, Amorim Energia (a privately held Portuguese company in which Sonangol, the national oil company of Angola, holds a minority stake), Rede Electrica Nacional (REN), and Caixa Geral de Depositos (a primary Portuguese financial institution). On September 26, 2006, in accordance with the

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Italy (Gela): GreenStream - Gas terminal

 

agreement, Galp’s regulated activities comprising a high pressure network, storage sites and a regasification terminal located in Sines were spinned-off and sold to REN which exited Galp capital on October 18, 2006.
On October 24, 2006, the Portuguese State divested part of its stake in Galp through an IPO. At the same time, Galp shares were registered on the national Portuguese stock exchange.
The shareholders of Galp post-IPO are: Eni (33.34%), Amorim Energia (33.34%), the Portuguese State (7.00%), Iberdrola (4%), Caixa (1%) and Setgas (0.04%); floating shares represent 21.28 % of the share capital.

Upgrade of import gaslines
Eni started implementing the upgrading plan of the natural gas import gaslines TTPC from Algeria and TAG from Russia.

TTPC - Algeria
The transport capacity of the TTPC gasline from Algeria is expected to be increased by 6.5 bcm/y of which a 3.2 bcm/y portion is planned to come on line on April 1, 2008, and a 3.3 bcm/y portion on October 1, 2008. Capital expenditure is expected at euro 450 million, increasing the amount initially budgeted in 2005 due to cost overruns and revisions of the engineering of the project. When the upgrading is fully operational, the gasline will deploy a transport capacity of 33.5 bcm/y.
A corresponding capacity on the TMPC downstream gasline is already available. TMPC crosses underwater the Sicily channel. The first portion of the TTPC upgrade was assigned to third parties in November 2005.
  The procedure to assign the second portion was closed in February 2007.

TAG - Russia
The transport capacity of the TAG gasline from Russia is expected to increase by 6.5 bcm/y coming on line on October 1, 2008. Expected capital expenditure amounts to euro 253 million; Eni’s share of this expenditure is 94%. A 3.2 bcm portion of the upgrade was assigned to third parties in February 2006 and the procedure assigning the residual portion has been defined.
At the beginning of 2007, a previously implemented upgrade of this gasline came on line in order to allow the build up of the fourth supply contract from Russia. As a result, the gasline transport capacity increased from 33 to 37 bcm/y. The ongoing upgrading plan is expected to increase the gasline transport capacity to 44 bcm/y by 2009.

GreenStream - Libya
Eni plans to upgrade the GreenStream import gasline from Libya in order to expand volumes input in the national transport network by 3 bcm/y. Said upgrade is expected to come on line by 2011 and to entail an expenditure of euro 84 million.
When the ongoing plan of upgrading the TTPC and TAG gasline is fully operational and taking into account the full capacity of the GreenStream gasline from Libya currently in place (8 bcm/y), a total of approximately 21 bcm/y of new import capacity will be available to third parties on the basis of non-discriminating procedures of allocation (17.7 bcm of this new capacity have already been allocated to third parties).

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Italy (Panigaglia): Regasification terminal

Regasification terminal
Eni plans to build a new regasification terminal located off the Adriatic coast and to increase the capacity of the Panigaglia plant. These two projects are expected to upgrade the import capacity to Italy by 8 and 4.5 bcm/y, respectively, when fully operational. The planned start-up is expected by 2013 and 2014, respectively. The capital expenditure expected for the offshore regasification project amounts to approximately euro 800 million. In 2006, preliminary studies were performed in order to screen potential sites where the terminal may be located and on the configuration of the plant.

Agreement between Eni and Gazprom
On November 14, 2006, Eni and Gazprom signed a broad strategic agreement. This agreement sets up an international alliance enabling the two companies to launch joint projects in the mid and downstream gas, in the upstream and technological cooperation. This agreement is a major step towards the security of energy supply to Italy.

i) Midstream and downstream gas
The duration of Russian gas supply contracts to Eni is extended until 2035, confirming that Eni is presently the world’s single largest customer of Gazprom. Through this agreement, starting from 2007, Gazprom is expected to sell increasing volumes of gas directly on the Italian market, building up to some 3 bcm in 2010 and to maintain such level in subsequent years for the duration of said long term supply contract. Volumes expected to be sold by Gazprom will be subtracted from volumes supplied to Eni under the fourth

  long-term supply contract. In 2007, Eni expects to reduce its supplies from Gazprom by 1 bcm, and Gazprom to sell approximately 1 bcm under this scheme.

ii) Upstream
Eni and Gazprom have identified major projects (companies and assets) in Russia and outside Russia that will be jointly pursued by the two partners. Eni and Gazprom have agreed to work with each other on an exclusive basis on these projects, which are expected to be finalized by the end of 2007.

iii) Technological cooperation and development
Eni and Gazprom will sign specific agreements in the following areas:
  • long-distance gas transportation. In this sector Eni and Snam Rete Gas will provide their know-how and expertise, including proprietary transport technology TAP (high pressure transmission) for the development of Russia’s gas transportation system;
  • development of LNG projects for the global gas market.

Agreement between Eni and Nigeria LNG
Eni signed a twenty-year sale and purchase agreement with Nigeria LNG (NLNG) Limited for the purchase of 1.375 mmtonnes/y (equivalent to approximately 2 bcm/y) of (LNG). LNG volumes sold to Eni are part of the volumes which are expected to be produced from the expansion of the capacity of the Bonny plant by means of the installation of a seventh train expected to come into operation in 2012.
LNG will be delivered by Nigeria LNG to the terminal of Cameron, Louisiana, where Eni already holds regasification capacity for about 6 bcm/year and will be sold to the US market. The volumes of LNG delivered to Eni through this agreement represent about 17% of the whole production of Bonny’s Train 7 expansion.
This agreement will make a further sizeable contribution to Eni's supply portfolio, enabling the company to strengthen its activities in the US and its role as leading player in the global LNG market.

Toscana project
On January 24, 2006, Eni, Italgas (Eni’s interest 100%) and the local authorities partners of Fiorentina Gas SpA (Eni’s interest 51.03%) and Toscana Gas SpA (Eni’s interest 46.1%), signed a framework agreement for developing an alliance in the field of natural gas distribution and sale in the Toscana Region.

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As a part of the agreement, Toscana Energia SpA (Eni’s interest 48.72%) was established upon contribution in-kind of the partners’ stakes in the distribution companies Fiorentina Gas and Toscana Gas.
The local authorities partners of Toscana Energia SpA hold the responsibility for strategic decisions and control, while Eni maintains operating and management responsibilities, being the industrial partner of the initiative. In addition, this agreement provides for Fiorentina Gas Clienti SpA (Eni’s interest 100%) to be merged into Toscana Gas Clienti SpA (Eni’s interest 46.1%, Tuscan municipalities 53.9%), resulting in the establishment of a regional selling company under Eni’s control (79.22%), re-named Toscana Energia Clienti and boasting 600 thousand clients and sale volumes of 1.1 bcm/y in 147 Tuscan municipalities.
The Italian Antitrust Authority authorized this transaction on July 20, 2006. The merger deed was defined on February 22, 2007, effective from March 1, 2007.

Restructuring power activities and launching of Dual Offer
In 2006, the G&P division started a project aiming at revamping the power generation business.
Under this project, the G&P division is expected to conduct directly the marketing activity of electricity, previously conducted by EniPower, starting in 2007. This scheme will allow the integrated management of marketing activities of gas and electricity and the development of a joint-offer of natural gas and electricity to customers.


Regulatory framework

Determination of reference prices for non eligible customers at December 31, 2002 - Resolutions No. 248/2004 and 134/2006 of the Italian Authority for Electricity and Gas
With a decision of November 13, 2006, the Council of State concluded the dispute between operators of the natural gas business, among which Eni, and the Italian Authority for Electricity and Gas related to Resolution No. 248 of December 29, 2004 “Determination of reference prices for non eligible customers at December 31, 2002” confirming the existence of formal flaws impairing the efficacy of the appeal presented by the Authority against the first degree decision that annulled the Authority’s decision against operators.
As far as the substance of the appeal is concerned, the Council of State previously stated that the Authority is entitled to hold such powers as to regulate certain activities of the energy sector in Italy which

  were liberalized by Law No. 239/2004 (in particular the sale of natural gas). Said regulatory powers enable the Authority to preserve competition and protect final clients. Based on these considerations and on the uncertainty of the efficacy of decisions implementing Resolution No. 248/2004 (among these No. 298/2005, No. 65/2006 and No. 134/2006) Eni’s management prepared its consolidated financial statements for 2006 by assessing the impact of the regulatory regime based on the indexation mechanism set out by Resolution No. 248/2004. This treatment was consistent with the one adopted in the preparation of quarterly and semi-annual accounts for 2006. In addition, Eni began to renegotiate the terms of supply contracts with its wholesale customers as provided for by Resolution No. 134/2006, which obliged Italian wholesalers to offer final clients new pricing terms which take into account the revision of the indexation mechanism of the raw material component as introduced by Resolution No. 248/2004. This provision applies only to wholesale contracts closed after the entry into force of Resolution No. 248/2004.
The provision accrued in the 2005 consolidated financial statements as an estimate of the impact of the indexation mechanism of Resolution No. 248/2004 in 2005 was deemed partially redundant as a result of the provisions of Resolution No. 134/2006. In fact, Resolution No. 134/2006 granted to companies complying with the renegotiation requirement an amount corresponding to 50% of the difference between the updating of the cost of raw materials calculated under Resolution No. 284/2005 and that calculated under the previous regime (under Resolution No. 195/2002) for the 2005 fiscal year as well as 50% of the variable compensation component in wholesale contracts. For further information on this matter see Eni’s Report on the First Half of 2006 - Operating Review - Gas & Power - Regulation - Determination of reference prices for non eligible customers at December 31, 2002 - Resolutions No. 248/2004 and No. 134/2006 of the Italian Authority for Electricity and Gas.
With Resolution No. 12/2007 of January 23, 2007, the Italian Authority for Electricity and Gas started a procedure to adopt a new indexation mechanism of the cost of raw material effective retroactively as of January 1, 2005. On March 1, 2007, the Authority published a consultative document.

Opening of an inquiry on prices
from the Italian Authority for Electricity and Gas

With Resolution No. 226/2006 of October 21, 2006,

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Italy: Control room of the Ferrera Erbognone EniPower station.

 

the Italian Authority for Electricity and Gas closed a formal inquiry against Eni that commenced with Resolution No. 107/2005, stating that Eni allegedly failed to comply with an obligation to transmit certain pieces of information regarding Eni’s natural gas import contracts to the Authority. Therefore, the Authority fined Eni by an amount of euro 10 million.
In spite of the circumstance that Eni spontaneously transmitted the requested pieces of information, the Authority objected to the fact that Eni delayed the fulfilment of its obligation to transmit said information, resulting in a behaviour in breach of the rules requiring the establishment of information flows intended to allow the Authority to perform its tasks. Eni filed a claim against the Authority’s decision before the Regional Administrative Court of Lombardy. For further information on this matter see Eni’s Report on the First Half of 2006 - Operating Review - Gas & Power - Regulation - Opening of an inquiry on prices from the Authority for Electricity and Gas.
Eni accrued a provision for this matter.

Inquiry of the Italian Authority for Electricity and Gas on behaviors of operators selling natural gas to end customers
With Resolution No. 235/06 of November 6, 2006, the Italian Authority for Electricity and Gas closed the inquiry that started in October 2005, on the commercial behavior of companies selling natural gas to end customers located in urban centers (residential, services, commercial activities and small enterprises) aiming at acquiring new customers or re-acquiring customers transferred to other sellers, with particular reference to hurdles posed by companies to customers wishing to leave one distributor or to the entry of competitors on the market. In its final report,
  the Authority confirmed the existence of certain critical points about the real level of competition within this market segment and proposed different options to complete and adjust the regulatory framework in order to overcome acknowledged deficiencies.

Resolution No. 137/2002 of the Italian Authority for Electricity and Gas - Access to transport services and Network Code of Snam Rete Gas
The Italian Authority for Electricity and Gas, with Resolution No. 137/2002, defined the criteria for regulating access to national natural gas transport networks, in particular the issue of priority. Eni filed a claim against this decision with the Regional Administrative Court of Lombardy that was partially accepted with the Court’s resolution on December 2004. The Authority filed a claim against this decision with the Council of State and informed Eni on February 19, 2004. The hearing for the discussion of this case has not yet been scheduled.

Legislative Decree No. 164/2000
Legislative Decree No. 164/2000 imposed thresholds to operators until December 31, 2010 in relation to a percentage share of domestic consumption set as follows: (i) 75%, from January 1, 2002, for imported or domestically produced natural gas volumes input in the domestic transmission network destined to sales; this percentage decreases by 2 percentage points per year until it reaches 61% in 2009; (ii) 50% from January 1, 2003 for sales to final customers. These ceilings are calculated net of volumes consumed in operations and

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in the case of sales also net of losses. The decree also provides for periodic controls of the respect of said ceilings. This control is performed each year by the Italian Antitrust Authority by comparing the allowed three-year average percent share of domestic consumption for both input volumes and sales volumes with the one actually achieved by each operator. In particular, 2006 closes the third three-year regulated period for natural gas volumes input in the domestic transmission network, for which the allowed percentage was 69% of domestic consumption of natural gas, and the second three-year regulated period for sales volumes. Eni’s presence on the Italian market complied with said limits.


POWER GENERATION
Eni’s electricity business is conducted by EniPower SpA and its subsidiaries owning power stations located at Eni’s sites in Ferrera Erbognone, Ravenna, Livorno, Taranto, Mantova, Brindisi and Ferrara with an installed capacity of 4.9 gigawatts as of December 31, 2006.
Eni is implementing an upgrading plan of its power generation capacity, targeting an installed capacity of 5.5 gigawatt in 2010. When this capacity is on line in 2010, production volumes are expected at 31 terawatthour, corresponding to approximately 8% of expected volumes of electricity generated in Italy by that year. Planned capital expenditure amounts to approximately euro 2.4 billion, of these euro 2 billion have already been deployed.
The development plan has been completed at all sites except for Ferrara (Eni’s interest 51%), where in partnership with Swiss company EGL AG, construction of two new 390 megawatt combined cycle units is

  underway. This will bring installed capacity to 840 megawatt and with start-up is expected in the second half of 2007. Moreover, Eni has planned the installation of a new 240 megawatt combined cycle unit located in Taranto (current capacity 75 megawatt).
New installed generation capacity uses the combined cycle gas fired technology (CCGT), ensuring a high level of efficiency and low environmental impact. In particular, management estimates that for a given amount of energy (electricity and heat) produced, the use of the CCGT technology on a production of 30 terawatthour reduces emissions of carbon dioxide by approximately 11 million tonnes, as compared to emissions using conventional power generation technology.
In 2006, electricity production sold was 24.82 terawatthour, up 2.05 terawatthour or 9% as compared to 2005. Increased production reflected the ramp-up of the three combined cycle units at the Brindisi plant entering full commercial operation since September 2006 (up approximately 3 terawatthour) and of the two combined cycle units at the Mantova plant fully operational in 2006 (up 0.9 terawatthour). These increases were offset in part by the standstill of the Ravenna power plant (down 0.85 terawatthour) due to maintenance activity.
Eni also purchased 6.21 terawatthour from third parties in and outside Italy. Sales of steam amounted to 10,287 million tonnes, down 3.5% from 2005.
Approximately 55% of sales were directed to end users, 28% to the Electricity Exchange, 8% to GRTN/Terna (under CIP 6/92 contracts and imbalances in input) and 9% to wholesalers. All the steam produced was sold to end users.

 

        2004   2005   2006   Change   % Ch.
       
 
 
 
 
Purchases                                  
Natural gas  

(mmcm)

 

2,617

   

4,384

   

4,775

   

391

   

8.9

 
Other fuels  

(ktoe)

 

784

   

659

   

616

   

(43

)  

(6.5

)
Include cracking steam      

89

   

96

   

136

             
Sales                                  
Electricity production sold  

(terawatthour)

 

13.85

   

22.77

   

24.82

   

2.05

   

9.0

 
Electricity trading  

(terawatthour)

 

3.1

   

4.79

   

6.21

   

1.42

   

29.6

 
Steam  

(ktonnes)

 

10,040

   

10,660

   

10,287

   

(373

)  

(3.5

)
       

 

 

 

 

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Capital expenditure
Capital expenditure in the Gas & Power segment totaled euro 1,174 million and related essentially to:(i) development and maintenance of Eni’s primary transport network in Italy (euro 627 million); (ii) the continuation of the construction of combined cycle
  power plants (euro 229 million), in particular at the Ferrara and Brindisi sites; (iii) development and maintenance of Eni’s natural gas distribution network in Italy (euro 158 million).

 

Capital expenditure   (million euro)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Italy  

1,236

   

1,066

   

1,014

   

(52

)  

(4.9

)
Outside Italy  

215

   

86

   

160

   

74

   

86.0

 
   

1,451

   

1,152

   

1,174

   

22

   

1.9

 
Market  

56

   

40

   

63

   

23

   

57.5

 
Italy  

36

   

2

   

0

   

(2

)  

(100.0

)
Outside Italy  

20

   

38

   

63

   

25

   

65.8

 
Distribution  

187

   

182

   

158

   

(24

)  

(13.2

)
Transport  

757

   

691

   

724

   

33

   

4.8

 
Italy  

562

   

643

   

627

   

(16

)  

(2.5

)
Outside Italy  

195

   

48

   

97

   

49

   

102.1

 
Power generation  

451

   

239

   

229

   

(10

)  

(4.2

)
   

1,451

   

1,152

   

1,174

   

22

   

1.9

 
   

 

 

 

 

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Refining & Marketing

 

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)   (million euro)  

26,089

 

33,732

 

38,210

Operating profit      

1,080

 

1,857

 

319

Adjusted operating profit      

923

 

1,214

 

790

Adjusted net profit      

674

 

945

 

629

Capital expenditure      

693

 

656

 

645

Adjusted capital employed, net      

4,835

 

5,326

 

5,766

ROACE adjusted   (%)  

13.0

 

18.2

 

10.7

Refining throughputs on own account   (mmtonnes)  

37.69

 

38.79

 

38.04

Refining throughputs of wholly-owned refineries      

26.75

 

27.34

 

27.17

Balanced capacity of wholly-owned refineries   (kbbl/d)  

504

 

524

 

534

Balanced capacity utilization rate   (%)  

100

 

100

 

100

Retail sales of petroleum products on Agip branded network in Europe   (mmtonnes)  

12.35

 

12.42

 

12.48

Agip branded service stations in Europe at period end   (units)  

6,225

 

6,282

 

6,294

Average throughput of Agip branded service stations in Europe   (kliters)  

2,488

 

2,479

 

2,470

Employees at year end   (units)  

9,224

 

8,894

 

9,437

       
 
 
     
(a)   Before elimination of intersegment sales.

Financial results
› In 2006, adjusted net profit was down euro 316 million to euro 629 million, or 33.4%, mainly due to a decline in refining margins as a result of a weak trading environment

› Eni’s realized refining margins recorded a better trend than market reference margins reflecting Eni’s refinery capacity to process heavy crudes which are discounted as compared to the Brent crude market benchmark, thus resulting in a higher profitability of the heavy barrel

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› Return on average capital employed was 10.7% on an adjusted basis, declining from 2005 (18.2% in 2005)

› Capital expenditure totalled euro 645 million and mainly related to projects aimed at improving flexibility and yields of refineries and upgrading the refined product retail network in Italy and in the rest of Europe

Operating results
› Refining throughputs on own account in Italy and outside Italy (38.04 mmtonnes) declined by 0.75 mmtonnes from 2005, down 1.9%, due mainly to higher maintenance standstills, particularly at third party refineries, while wholly-owned refineries achieved stable processing levels

› Retail sales of refined products in Italy (8.66 mmtonnes) declined 1% from 2005 mainly due to competitive pressure. This decrease was more than offset by a growth in retail volumes marketed in the rest of Europe (3.82 mmtonnes, up 4.1%), mainly in Germany and Spain

› Sales on the wholesale market in Italy (10.06 mmtonnes) were down 4% due primarily to the decline registered in the fourth quarter due to the impact of mild weather conditions. This decline was partially offset by a growth in volumes marketed on wholesale markets in the rest of Europe (4.6 mmtonnes, up 2.2%), in particular in Germany and Spain

 

Supply and trading
In 2006, a total of 65.70 mmtonnes of oil were purchased (66.48 mm in 2005), of which 36.81 mmtonnes from Eni’s Exploration & Production1 segment, 18.16 mmtonnes under long-term contracts with producing countries and 10.73 mmtonnes on the spot market. Some 21% of oil purchased came from West Africa, 21% from North Africa, 18% from countries of the former Soviet Union, 14% from the Middle East,
  14% from the North Sea, 7% from Italy and 5% from other areas. Some 30.66 mmtonnes were traded, down 1.3% from 2005. In addition, 3.18 mmtonnes of intermediate products were purchased (3.58 in 2005) to be used as feedstock in conversion plants and 16 mmtonnes of refined products (16.21 in 2005) were purchased to be sold on markets outside Italy (11.48 mmtonnes) and on the Italian market (4.52 mmtonnes) as a complement to own production.

     
(1)   The Refining & Marketing segment purchased approximately two-thirds of the Exploration & Production segment’s oil and condensate production and resold on the market those crudes and condensates that are not suited for processing in its own refineries due to their characteristics or geographic area.

 

Supply of oil   (mmtonnes)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Production outside Italy   31.7     32.86     32.76     (0.10 )   (0.3 )
Production in Italy   4.03     4.44     4.05     (0.39 )   (8.8 )
Total production   35.73     37.30     36.81     (0.49 )   (1.3 )
Spot markets   11.42     14.33     10.73     (3.60 )   (25.1 )
Long-term contracts   19.9     14.85     18.16     3.31     22.3  
    67.05     66.48     65.70     (0.78 )   (1.2 )
   

 

 

 

 

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Refining
In 2006, refining throughputs on own account in Italy and outside Italy were 38.04 mmtonnes, down 0.75 mmtonnes from 2005, or 1.9%, owing to lower throughputs on third party refineries as a consequence of an accident occurred at the Priolo refinery and a maintenance standstill at the Milazzo refinery (Eni’s interest 50%).
Refining throughputs on own account were stable. In particular, refining throughputs increased at the Venice, Gela and Taranto refineries and decreased at the Sannazzaro refinery due to a maintenance standstill of the catalytic cracking unit and the visbreaking unit, and at the Livorno refinery due to general maintenance activity.
In April, a new unit for heavy residue gasification started operating at the Sannazzaro refinery.
Total throughputs on wholly-owned refineries (27.17 mmtonnes) decreased 0.17 mmtonnes from 2005, down 0.6%; balanced capacity of refineries was fully utilized. Approximately 35.9% of volumes of processed oil was supplied by Eni’s Exploration & Production segment (32.3% in 2005), representing a three percentage point increase from 2005. Incremental volumes of some 1.1 mmtonnes of equity oil processed related to higher supplies of heavy oil from Nigeria (due to the start-up of the Bonga field) and from Sicily, against a reduction of supplies of the Libyan Bu-Attifel oil processed at Priolo.


Distribution of refined products
In 2006, sales volumes of refined products (51.13 mmtonnes) were down 500 ktonnes from 2005, or 1%, mainly due to lower wholesale volumes (down
 
320 ktonnes) as a consequence of mild weather conditions in the last part of the year adversely affecting heating products sales. In addition, lower volumes were supplied to the petrochemical sector (down 460 ktonnes) owing to the technical accident that occurred at the Priolo refinery. These declines were offset in part by higher sales to oil companies and traders and by a growth in retail sales on the Agip branded network in Italy and outside Italy (up 60 ktonnes).
The impact of the Italiana Petroli (IP) divestment, effective September 1, 2005 (1.3 mmtonnes), was partly offset by supply of fuels to the same company under a five-year contract signed concurrently with the divestment.

 

Petroleum products availability   (mmtonnes)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Italy                              
Refinery intake in wholly-owned refineries  

26.75

   

27.34

   

27.17

   

(0.17

)  

(0.6

)
Refinery intake for third parties  

(1.50

)  

(1.70

)  

(1.53

)  

0.17

   

(10.0

)
Refinery intake in non-owned refineries  

8.10

   

8.58

   

7.71

   

(0.87

)  

(10.1

)
Consumption and losses  

(1.64

)  

(1.87

)  

(1.45

)  

0.42

   

(22.5

)
Products available  

31.71

   

32.35

   

31.90

   

(0.45

)  

(1.4

)
Purchases of finished products and change in inventories  

5.07

   

4.85

   

4.45

   

(0.40

)  

(8.2

)
Finished products transferred to foreign cycle  

(5.03

)  

(5.82

)  

(5.35

)  

0.47

   

(8.1

)
Consumption for power generation  

(1.06

)  

(1.09

)  

(1.10

)  

(0.01

)  

(0.9

)
Products sold  

30.69

   

30.29

   

29.90

   

(0.39

)  

(1.3

)
Outside Italy                              
Products available  

4.04

   

4.33

   

4.37

   

0.04

   

0.9

 
Purchases of finished products and change in inventories  

13.78

   

11.19

   

11.51

   

0.32

   

2.9

 
Finished products transferred from Italian cycle  

5.03

   

5.82

   

5.35

   

(0.47

)  

(8.1

)
Products sold  

22.85

   

21.34

   

21.23

   

(0.11

)  

(0.5

)
Sales in Italy and outside Italy  

53.54

   

51.63

   

51.13

   

(0.50

)  

(1.0

)
   

 

 

 

 

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Sales of refined products in Italy and outside Italy   (mmtonnes)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Retail marketing  

10.93

   

10.05

   

8.66

   

(1.39

)  

(13.8

)
- Agip brand  

8.88

   

8.75

   

8.66

   

(0.09

)  

(1.0

)
- IP brand  

2.05

   

1.30

         

(1.30

)  

(100.0

)
Wholesale marketing  

10.7

   

10.48

   

10.06

   

(0.42

)  

(4.0

)
Petrochemical  

3.05

   

3.07

   

2.61

   

(0.46

)  

(15.0

)
Other sales (a)  

6.01

   

6.69

   

8.57

   

1.88

   

28.1

 
Sales in Italy  

30.69

   

30.29

   

29.90

   

(0.39

)  

(1.3

)
Retail marketing rest of Europe  

3.47

   

3.67

   

3.82

   

0.15

   

4.1

 
Retail marketing Africa and Brazil  

0.57

                         
Wholesale marketing outside Italy  

5.30

   

4.50

   

4.60

   

0.10

   

2.2

 
of which wholesale marketing rest of Europe  

3.94

   

4.10

   

4.19

   

0.09

   

2.2

 
Other sales (a)  

13.51

   

13.17

   

12.81

   

(0.36

)  

(2.7

)
Sales outside Italy  

22.85

   

21.34

   

21.23

   

(0.11

)  

(0.5

)
   

53.54

   

51.63

   

51.13

   

(0.50

)  

(1.0

)
   

 

 

 

 

         
(a)   Includes bunkering, sales to oil companies and MTBE sales.

 

Retail sales in Italy
Retail volumes of refined products marketed on the Italian network (8.66 mmtonnes) were down 1.39 mmtonnes from 2005, or 13.8% mainly due to the IP divestment as outlined above.
Retail volumes marketed on the Agip branded network (8.66 mmtonnes) decreased of some 90 ktonnes, down 1%, due to a higher competitive pressure. This decline essentially concerned gasoline and BluDiesel, following a pattern aligned with national consumption trends. Market share of the Agip branded network was down 0.4 percentage points from 29.7% to 29.3% in 2006; average throughput in terms of gasoline and diesel fuel was 2,463 kliters, down 1.8% from 2005.
At December 31, 2006, Eni’s retail distribution network in Italy consisted of 4,356 service stations, seven more than at December 31, 2005 (4,349 units), resulting from the opening of new service stations (20 units) and the positive balance of acquisitions/releases of lease concessions (11 units), offset in part by the closing of service stations with low throughput (21 units) and the release of 3 service stations under highway concessions.
Retail volumes of BluDiesel – a high performance and low environmental impact diesel fuel – amounted to about 726 ktonnes (840 mmliters), down 14.8% from 2005, mainly due to an increasingly high sensitivity of consumers to retail prices of fuels in light of their escalation that pushed prices to historical peaks. At year-end, virtually all Agip branded service stations marketed BluDiesel (about 4,061 equal to 93%).
Retail volumes of BluSuper – a high performance and low environmental impact gasoline – amounted to
  about 98 ktonnes (114 mm liters), down 9% from 2005, showing a trend similar to the one of BluDiesel. At year-end, service stations marketing BluSuper totaled 2,316 (1,719 at December 31, 2005) corresponding to approximately 53% of Eni’s network.
In 2006, Eni continued its Do-It-Yourself campaign which allows participating customers to obtain discounts or gifts (under agreements with Vodafone and Coop) in proportion to volumes of fuel purchased at self-service outlets, charged on an electronic card. Further bonuses are offered to the most faithful customers. At year-end, the number of active cards was approximately 3.9 million; turnover on cards increased by 3% from 2005. Volumes of fuel marketed under this initiative represented some 39% of total volumes

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Italy: Storage unit.

 

marketed on the Agip branded outlets joining the campaign, and some 31% of overall volumes marketed on the Agip network.

Retail sales outside Italy
In recent years, Eni’s strategy focused on selectively growing its market share, by means of acquisition of assets in European areas with interesting profitability perspectives, mainly in Central-Eastern Europe (in particular Southern Germany, Austria, the Czech Republic and Hungary), in South-Eastern France and the Iberian Peninsula. In pursuing such growth, Eni has been able to reap synergies in these areas facilitated by their proximity to Eni’s production and logistic facilities.
Over the last five years, retail volumes of refined products marketed in the rest of Europe have grown more than 50% (equal to a compound average growth rate of 9%). In 2006, retail sales were 3.82 mmtonnes, up 150 ktonnes from 2005, or 4.1%, particularly in Germany, Spain and Austria due to the ramp-up of new stations purchased or built with higher throughput than the average level of Eni’s network, while a few less efficient outlets were dismissed.
Volume growth was driven primarily by increased sales of diesel fuel and LPG, while gasoline volumes declined.
At December 31, 2006, Eni’s retail distribution network
  in the rest of Europe consisted of 1,938 units, an increase of five units from December 31, 2005. The network’s evolution was as follows: (i) 31 service stations were acquired in Austria and France; (ii) 24 new outlets were opened in Spain and Austria; (iii) 46 low throughput service stations were closed in Spain and France; (iv) a negative balance of acquisitions/releases of lease concessions (down four units) was recorded, with negative changes in Portugal and Germany, positive ones in France and Spain. Average throughput (2,486 kliters) was up 2.4%.

Wholesale and other sales
Sales volumes on wholesale markets in Italy (10.06 mmtonnes) were down 0.42 mmtonnes from 2005, or 4%, reflecting mainly a decline in domestic consumption related to mild weather conditions in the fourth quarter of the year, with higher temperatures than the seasonal average. This decline mainly involved heating oil and fuel oil, as sales of the latter were also negatively impacted by a process of progressive substitution of fuel oil by natural gas as feedstock for power plants. Instead, jet fuel volumes increased from a year ago reflecting a recovery in the airline industry.
Sales on wholesale markets outside Italy (4.60 mmtonnes) increased 100 ktonnes, or 2.2%, mainly due to higher sales of diesel fuel in Germany and Spain.

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Other sales (21.38 mmtonnes) increased by 1.52 mmtonnes, or 7.7%, mainly due to supplies to IP (up 1.3 mmtonnes) despite its divestment in September 2005, and to sales to oil companies and traders (up 220 ktonnes).
Supplies of feedstock to the petrochemical industry (2.61 mmtonnes) declined by 460 ktonnes as a consequence of an accident that occurred at the Priolo refinery where Eni had a processing contract to produce feedstock for its nearby petrochemical complex. This agreement expired on December 31, 2006.
  Capital expenditure
In 2006, capital expenditure in the Refining & Marketing segment amounted to euro 645 million and concerned: (i) refining, supply and logistics (euro 376 million) in Italy, aiming at improving flexibility and yields of refineries, in particular the start-up of construction of a new hydrocracking unit at the Sannazzaro refinery; (ii) upgrade and restructuring of the retail network in Italy (euro 125 million), including construction of new outlets; (iii) upgrade of the retail network in the rest of Europe (euro 98 million), including purchase and realization of new outlets, and, to a lesser extent, restructuring of existing ones.

 

Capital expenditure   (million euro)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Italy  

625

   

585

   

547

   

(38

)  

(6.5

)
Outside Italy  

68

   

71

   

98

   

27

   

38.0

 
   

693

   

656

   

645

   

(11

)  

(1.7

)
Refining, supply and logistics  

420

   

349

   

376

   

27

   

7.7

 
Italy  

420

   

349

   

376

   

27

   

7.7

 
Marketing  

232

   

225

   

223

   

(2

)  

(0.9

)
Italy  

164

   

154

   

125

   

(29

)  

(18.8

)
Outside Italy  

68

   

71

   

98

   

27

   

38.0

 
Other activities  

41

   

82

   

46

   

(36

)  

(43.9

)
   

693

   

656

   

645

   

(11

)  

(1.7

)
   

 

 

 

 

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Petrochemical

 

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

5,331

 

6,255

 

6,823

Operating profit      

320

 

202

 

172

Adjusted operating profit      

263

 

261

 

219

Adjusted net profit      

242

 

227

 

174

Capital expenditure      

148

 

112

 

99

Production  

(ktonnes)

 

7,118

 

7,282

 

7,072

Sales of petrochemical products      

5,187

 

5,376

 

5,276

Average plant utilization rate  

(%)

 

75.2

 

78.4

 

76.4

Employees at year end  

(units)

 

6,565

 

6,462

 

6,025

       
 
 
     
(a)   Before elimination of intersegment sales.

› Adjusted net profit was euro 174 million, down euro 53 million from a year ago, or 23.3%, due to a poor operating performance dragged down by a weak petrochemical environment in the first half of 2006

› Sales of petrochemical products were 5,276 ktonnes, down 100 ktonnes from last year, or 1.9%, due to a lower product availability as a consequence of the outage of the Priolo cracker owing to an accident that occurred at the nearby refinery, negatively impacting the entire production cycle

› Petrochemical production volumes were 7,072 ktonnes, down 209 ktonnes from 2005, or 2.9%, mainly due to the outage of the Priolo cracker and related plants

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Sales - production - prices
In 2006, sales of petrochemical products (5,276 ktonnes) decreased by 100 ktonnes from 2005, down 1.9%. Main declines concerned: (i) basic petrochemicals (down 4.6%), due to lower product availability as a consequence of the outage of the Priolo cracker due to an accident occurred at the nearby refinery; (ii) elastomers (down 2.3%), due to a slow recovery of the Ferrara and Ravenna plant performance after maintenance activities carried out in the first half of the year; (iii) intermediates (down 10.4%), due to a weak demand. These negatives were offset in part by increased sales of polyethylene (up 3.2%) and aromatics (in particular, xylenes up 4.8%) reflecting good market conditions.
Production (7,072 ktonnes) declined by 209 ktonnes from 2005, down 2.9%, in particular in elastomers, polyethylene and basic petrochemicals, where lower production due to the standstill of the Priolo cracker was offset in part by higher production at the Porto Marghera, Sarroch and Dunkerque plants. Styrene
  production also increased reflecting poor performance in 2005 affected by plant outages and technical issues.
Nominal production capacity was in line with 2005. Rising nominal capacity in a few crackers was offset in part by the outage of the Priolo cracker and related plants. Average plant utilization rate calculated on nominal capacity declined by 2 percentage points from 78.4% to 76.4%, mainly due to lower production volumes.
Approximately 35.2% of total production was directed to Eni’s own productions cycle (35.8% in 2005). Oil-based feedstock supplied by Eni’s Refining & Marketing Division covered 10% of requirements (23% in 2005).
Prices of Eni’s main petrochemical products increased on average by 12%; all business areas posted increases. The most relevant increases were registered in: (i) olefins (up 16.5%), in particular ethylene and propylene; (ii) aromatics (up 19.6%), in particular xylenes; (iii) polyethylene (up 12%) with increases in all products; (iv) styrenes (up 8.2%), in particular styrene and polystyrenes; (v) elastomers (up 4.2%), in particular BR and TPR rubbers.

 

Product availability   (ktonnes)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Basic petrochemicals   4,236     4,450     4,275     (175 )   (3.9 )
Styrene and elastomers   1,606     1,523     1,545     22     1.4  
Polyethylene   1,276     1,309     1,252     (57 )   (4.4 )
Production   7,118     7,282     7,072     (210 )   (2.9 )
Consumption of monomers   (2,616 )   (2,606 )   (2,488 )   118     (4.5 )
Purchases and change in inventories   685     700     692     (8 )   (1.1 )
    5,187     5,376     5,276     (100 )   (1.9 )
   

 

 

 

 

 

Sales   (ktonnes)   2004   2005   2006   Change   % Ch.
       
 
 
 
 
Basic petrochemicals   2,766     3,022     2,882     (140 )   (4.6 )
Styrene and elastomers   1,038     1,003     1,000     (3 )   (0.3 )
Polyethylene   1,383     1,351     1,394     43     3.2  
    5,187     5,376     5,276     (100 )   (1.9 )
   

 

 

 

 

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Business areas
Basic petrochemicals
Sales of basic petrochemicals of 2,882 ktonnes declined by 256 ktonnes from 2005, down 4.6%, mainly due to the outage of the Priolo cracker. Declines were registered in olefins (down 1.5%), intermediates (down 10.4%) and benzene (down 23%). Increasing sales in xylene (up 4.8%) and ethylene (up 3.2%) reflected higher product availability at other plants.
Basic petrochemical production (4,275 ktonnes) decreased by 175 ktonnes, down 3.9%. Lower production resulting from the Priolo cracker outage was offset in part by higher production at the Porto Marghera and Dunkerque.

Styrene and elastomers
Styrene sales (587 ktonnes) were slightly higher from 2005 (up 1.1%). Increasing sales in styrene reflected higher production availability. Declines were registered in compact polystyrene (down 1.5%) due to a lack of feedstock owing to the outage of the Priolo cracker and in ABS/SAN due to the outage of the EniPower power station with a negative impact on the Mantova plant.
Elastomers sales (413 ktonnes) increased by 1.2% from 2005 excluding the impact of the shutdown of the Champagnier plant in the second half of 2005. Increases concerned all products, with the exception of BR rubbers (down 8%) due to a maintenance standstill of the Ravenna Neocis plant.
  Styrene production (1,088 ktonnes) increased by 3.8% reflecting mainly technical issues and a maintenance standstill that occurred at the Mantova plant in 2005.
Elastomer production (457 ktonnes) decreased by 1.3% excluding the impact of the shutdown of the Champagnier plant, due to a weak demand in BR (down 8.5%) and SBR (down 3.6%) rubbers. Production volumes of other rubbers increased in line with trends registered in demand.

Polyethylene
Polyethylene sales (1,394 ktonnes) were up 43 ktonnes or 3.2%, from 2005, reflecting positive market conditions for LLPDE (up 9.3%) and HPDE (up 1.5%). These increases were offset by a decline in EVA (down 3.7%) due to certain technical issues at the Oberhausen plant.
Production (1,252 ktonnes) declined by 57 ktonnes, or 4.4%, mainly due to the standstill of the Priolo cracker and related plants.

Capital expenditure
In 2006, capital expenditure (euro 99 million; euro 112 million
in 2005) concerned efforts in upkeeping (euro 32 million), improving plant efficiency and streamlining (euro 32 million), environmental protection, safety and environmental regulation compliance (euro 23 million) and extraordinary and periodic maintenance (euro 12 million).

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Engineering & Construction

 

Key performance indicators  

2004

 

2005

 

2006

   
 
 
Net sales from operations (a)  

(million euro)

 

5,696

 

5,733

 

6,979

Operating profit      

203

 

307

 

505

Adjusted operating profit      

215

 

314

 

508

Adjusted net profit      

252

 

328

 

400

Capital expenditure      

186

 

349

 

591

ROACE adjusted   (%)  

10.5

 

12.0

 

12.8

Orders acquired      

5,784

 

8,395

 

11,172

Order backlog      

8,521

 

10,122

 

13,191

Employees at year end  

(units)

 

25,819

 

28,684

 

30,902

       
 
 
     
(a)   Before elimination of intersegment sales.

› Adjusted net profit was euro 400 million, up euro 72 million from a year ago or 22%, reflecting a better operating performance against the backdrop of favourable trends in the demand for oilfield services

› Return on average capital employed calculated on an adjusted basis was 12.8% in 2006, up 12% from 2005

› Orders acquired amounted to euro 11,172 million, up euro 2,777 million from 2005 (+33.1%), in particular in onshore activities

› Order backlog was euro 13,191 million at December 31, 2006 (euro 10,122 million at December 31, 2005)

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Activity for the year
Among the main orders acquired in 2006 were:
  • an EPC contract for Saudi Aramco for the construction of four trains for gas and crude separation with a total capacity of 1.2 mmbbl/d and production facilities within the development of the onshore Khursaniyah field in Saudi Arabia;
  • a contract for the conversion of an oil tanker into an FPSO unit with production capacity of 1.8 mmbbl for the development of the Gimboa field in the deep offshore of Angola for Sonangol P&P;
  • an EPIC contract for Burullus Gas Co for the construction of underwater systems for the development of eight new wells within the expansion plan of the Scarab/Saffron and Simian fields offshore the Nile Delta;
 
  • a 16-month long contract for the use of the semisubmersible drilling platform Scarabeo 7 in Nigeria for ExxonMobil.

Orders acquired amounted to euro 11,172 million, of these projects to be carried out outside Italy represented 91%, while orders from Eni companies amounted to 24% of the total. Eni’s order backlog was euro 13,191 million at December 31, 2006 (euro 10,122 million at December 31, 2005). Projects to be carried out outside Italy represented 90% of the total order backlog, while orders from Eni companies amounted to 20% of the total.

In February 2007, a contract for the construction of a new pipelayer has been signed. The unit, with a carrying capacity of 25 ktonnes and a lifting capacity of 600 tonnes by means of a crane, will be manufactered in China.

 

    (million euro)       2005   Full year 2006   Change   % Ch.
           
 
 
 
Orders acquired (a)  

8,395

 

11,172

 

2,777

 

33.1

Offshore construction  

3,096

 

3,681

 

585

 

18.9

Onshore construction  

4,720

 

4,923

 

203

 

4.3

Offshore drilling  

367

 

2,230

 

1,863

 

..

Onshore drilling  

212

 

338

 

126

 

59.4

of which:                
- Eni  

887

 

2,692

 

1,805

 

..

- Third parties  

7,508

 

8,480

 

972

 

12.9

of which:                
- Italy  

858

 

1,050

 

192

 

22.4

- Outside Italy  

7,537

 

10,122

 

2,585

 

34.3

   
 
 
 

 

    (million euro)       Dec. 31, 2005   Dec. 31, 2006   Change   % Ch.
           
 
 
 
Order backlog (a)  

10,122

 

13,191

 

3,069

 

30.3

Offshore construction  

3,721

 

4,283

 

562

 

15.1

Onshore construction  

5,721

 

6,285

 

564

 

9.9

Offshore drilling  

382

 

2,247

 

1,865

 

..

Onshore drilling  

298

 

376

 

78

 

26.2

of which:                
- Eni  

695

 

2,602

 

1,907

 

..

- Third parties  

9,427

 

10,589

 

1,162

 

12.3

of which:                
- Italy  

1,209

 

1,280

 

71

 

5.9

- Outside Italy  

8,913

 

11,911

 

2,998

 

33.6

   
 
 
 
     
(a)   Includes the Bonny project for euro 28 million in orders acquired and euro 101 million in order backlog.

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Capital expenditure
In 2006, capital expenditure in the Engineering & Construction segment (euro 591 million) concerned: (i) the conversion of the Margaux tanker ship into an FPSO vessel that will operate in Brazil on the Golfinho 1 field; (ii) maintenance and upgrading of equipment; (iii) fabrication and installation of facilities in the offshore phase of the Kashagan project in Kazakhstan.

CEPAV Uno and CEPAV Due
Eni holds interests in the CEPAV Uno (50.36%) and CEPAV Due (52%) consortia that in 1991 signed two contracts with TAV SpA for the construction of two railway tracks for high speed/high capacity trains from Milan to Bologna (under construction) and from Milan to Verona (in the design phase).
With regard to the project for the construction of the line from Milan to Bologna, an Addendum to the contract between CEPAV Uno and TAV was signed on June 27, 2003, redefining certain terms and conditions of the contract. Subsequently, the CEPAV Uno consortium requested a time extension for the completion of works and an additional payment amounting to euro 800 million. CEPAV Uno and TAV failed to solve this dispute amicably,
  and on April 27, 2006, CEPAV Uno notified TAV a request for arbitration as provided for under terms of the contract. At the end of 2006, the CEPAV Uno consortium had completed works corresponding to 75% of the total contractual price.
With regard to the project for the construction of the tracks from Milan to Verona, in December 2004, CEPAV Due presented the final project, prepared in accordance with Law No. 443/2001 on the basis of the preliminary project approved by an Italian governmental authority (CIPE). As concerns the arbitration procedure requested by CEPAV Due against TAV for the recognition of damage related to TAV’s belated completion of its tasks, in January 2007, the arbitration committee came to a partial decision in support of CEPAV Due confirming the recovery of higher incurred costs for design activities.
A technical survey is underway to establish a final evaluation of the compensation as requested by the arbitration committee.
A law decree revoking the framework contract for the construction of the Milan-Verona line is due to be published. Rights of the Consortium to recover costs incurred up to date for design activities are expected to be preserved.

 

    (million euro)       2005   2006   Change   % Ch.
           
 
 
 
Offshore construction  

262

 

390

 

128

 

48.9

Onshore construction  

20

 

53

 

33

 

165.0

Offshore drilling  

46

 

101

 

55

 

119.6

Onshore drilling  

13

 

36

 

23

 

176.9

Other  

8

 

11

 

3

 

37.5

Capital expenditure  

349

 

591

 

242

 

69.3

   
 
 
 

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Financial Review

 

 

 

Profit and Loss Account

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

57,545

    Net sales from operations  

73,728

   

86,105

   

12,377

   

16.8

 

1,377

    Other income and revenues  

798

   

783

   

(15

)  

(1.9

)

(41,592

)   Operating expenses  

(51,918

)  

(61,140

)  

(9,222

)  

(17.8

)

5

    of which non recurring items  

(290

)  

(239

)  

51

       

(4,931

)   Depreciation, amortization and impairments  

(5,781

)  

(6,421

)  

(640

)  

(11.1

)

12,399

    Operating profit  

16,827

   

19,327

   

2,500

   

14.9

 

(156

)   Net financial income (expense)  

(366

)  

161

   

527

   

..

 

820

    Net income from investments  

914

   

903

   

(11

)  

(1.2

)

13,063

    Profit before income taxes  

17,375

   

20,391

   

3,016

   

17.4

 

(5,522

)   Income taxes  

(8,128

)  

(10,568

)  

(2,440

)  

(30.0

)

42.3

    Tax rate (%)  

46.8

   

51.8

   

5.0

       

7,541

    Net profit  

9,247

   

9,823

   

576

   

6.2

 
      Pertaining to:                        

7,059

    - Eni  

8,788

   

9,217

   

429

   

4.9

 

482

    - minority interest  

459

   

606

   

147

   

32.0

 


     

 

 

 

 

Eni's net profit for 2006 was a record euro 9,217 million, up euro 429 million compared to 2005, or 4.9%. This increase reflected a better operating performance (up euro 2,500 million, or 14.9%), partially offset by a higher Group tax rate, which rose from 46.8% to 51.8%. The increase in the Group tax rate was recorded mainly in the Exploration & Production division due to: (i) the Algerian windfall tax on upstream earnings effective as from August 1, 2006 (with an overall impact of euro 328 million, of which euro 149 million pertaining to taxation for   the period and euro 179 million pertaining to the deferred tax impact); (ii) an increase in the supplemental tax rate implemented by the British Government, applicable to profit before taxes earned by operations in the North Sea, effective as from January 1, 2006, affecting both current taxation and deferred tax liabilities (with an overall impact of euro 198 million of which euro 107 million, pertaining to taxation for the period and euro 91 million pertaining to the deferred tax impact).

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2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

7,059

    Eni’s net profit  

8,788

   

9,217

   

429

   

4.9

 

(281

)   Exclusion of inventory holding (gains) losses  

(759

)  

33

   

792

       

(133

)   Exclusion of special items:  

1,222

   

1,162

   

(60

)      

5

    - non recurring items  

290

   

239

   

(51

)      

(138

)   - other special items  

932

   

923

   

(9

)      

6,645

    Eni’s adjusted net profit (a)  

9,251

   

10,412

   

1,161

   

12.5

 


     

 

 

 

     
(a)   For a definition and reconciliation of reported operating profit and reported net profit to adjusted results, which exclude inventory holding gains/losses and special items, see the paragraph “Reconciliation of reported operating profit and net profit to results on an adjusted basis” pages 66.

 

Eni's adjusted net profit for the year was up 12.5% to euro 10,412 million. Adjusted net profit is calculated by excluding an inventory holding loss of euro 33 million and special charges of euro 1,162 million (both amounts are net of the related fiscal effect).

Special charges for the year were principally related to asset impairments, impacting mainly assets in the Exploration & Production division, environmental provisions, redundancy incentives, risk provisions with respect to certain fines imposed by certain regulatory and antitrust authorities and a deferred tax charge, reflecting the windfall tax levied by the Algerian Government and the supplemental tax rate in the UK, as mentioned above.
  Return on average capital employed (ROACE) calculated on an adjusted basis for the twelve-month period ending December 31, 2006 was 22.7% (20.5% in 2005).

Eni's results benefited from a favorable trading environment, with a higher Brent crude oil price (up 19.8% from 2005) and higher selling margins on petrochemical products. These positives were partially offset by declining refining margins (margin on Brent was down 34.4%). Selling margins on natural gas were underpinned by a favorable trading environment. The euro appreciated by 1% over the dollar.

The break-down of adjusted net profit by division1 is shown in the table below:

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

4,033

    Exploration & Production  

6,186

   

7,279

   

1,093

   

17.7

 

2,290

    Gas & Power  

2,552

   

2,862

   

310

   

12.1

 

674

    Refining & Marketing  

945

   

629

   

(316

)  

(33.4

)

242

    Petrolchemicals  

227

   

174

   

(53

)  

(23.3

)

252

    Engineering & Construction  

328

   

400

   

72

   

22.0

 

(241

)   Other activities  

(297

)  

(301

)  

(4

)  

(1.3

)

(86

)   Corporate and financial companies  

(142

)  

54

   

196

   

..

 

(37

)   Unrealized profit in inventory (a)  

(89

)  

(79

)  

10

   

11.2

 

7,127

       

9,710

   

11,018

   

1,308

   

13.5

 
      of which:                        

482

    minority interest  

459

   

606

   

147

   

32.0

 

6,645

    Eni’s adjusted net profit  

9,251

   

10,412

   

1,161

   

12.5

 


     

 

 

 

     
(a)   Unrealized profit in inventory concerned intragroup sales of goods and services recorded in the assets of the purchasing division as of end of the period.

From January 1, 2006 Eni’s subsidiaries operating in diversified sectors (such as real estate services, insurance and financing intermediation, R&D and training services) are reported in the aggregate “Corporate and financing companies” with the exception of Tecnomare which is reported in the Exploration & Production division (previously all these diversified activities were reported in the aggregate “Other activities”). The “Other activities” aggregate includes only Syndial SpA, a subsidiary which runs minor petrochemical activities and reclamation and decommissioning activities pertaining to certain businesses which Eni exited in past years. In order to allow for comparison, 2005 data has been reclassified accordingly; 2004 data has not been reclassified.


     
(1)   For a definition and calculation method of adjusted net profit by division, see paragraph “Reconciliation of reported operating profit and net profit to results on an adjusted basis” page 66.

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The Group adjusted net profit for the year was supported by the increase reported in the:
  • Exploration & Production division (up euro 1,093 million, or 17.7%), reflecting a better operating performance (up euro 2.860 million) as a result of higher realizations in dollars (oil up 22.4% and natural gas up 17.8%) combined with increased production volumes sold (up 10.2 mmboe). These positives were offset in part by higher operating costs and amortization charges, and increased exploration expenses. Adjusted net profit for the year was also negatively affected by the effects of exchange rates and a higher tax rate (from 51.8 to 53.9%);
  • Gas & Power division (up euro 310 million, or 12.1%), reflecting a better operating performance (up euro 351 million) resulting from higher natural gas selling margins due to a favorable trading environment and the reduced impact of the tariff regime implemented by the Authority for Electricity and Gas with Resolution No. 248/2004. Growth in natural gas sales by consolidated subsidiaries (up 3.14 bcm, or 3.8%) and in volumes transported outside Italy contributed positively. On a negative note, transport activities in Italy posted lower operating results due to the tariff regime enacted by the Authority for Electricity and Gas with Resolution No. 166/2005 and distribution activities suffered from lower volumes. Adjusted net profit for the year was supported by a better performance of certain equity-accounted entities;
 
  • Engineering & Construction division (up euro 72 million or 22%), reflecting a better operating performance against the backdrop of favorable trends in the demand for oilfield services.

These increases were partly offset by lower adjusted net profit reported in the Refining & Marketing division (down euro 316 million, or 33.4%), due to a poor operating performance (down euro 424 million) dragged down by a weak refining environment, the appreciation of the euro over the dollar and the impact of a higher level of planned maintenance activity at refineries.
Divisional results were also adversely impacted by the weaker performance of marketing activities in Italy due to lower sales as a consequence of the mild weather conditions of the fourth quarter.

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Analysis of profit and loss account items

Net sales from operations

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

15,346

    Exploration & Production  

22,531

   

27,173

   

4,642

   

20.6

 

17,302

    Gas & Power  

22,969

   

28,368

   

5,399

   

23.5

 

26,089

    Refining & Marketing  

33,732

   

38,210

   

4,478

   

13.3

 

5,331

    Petrochemicals  

6,255

   

6,823

   

568

   

9.1

 

5,696

    Engineering & Construction  

5,733

   

6,979

   

1,246

   

21.7

 

1,279

    Other activities  

863

   

823

   

(40

)  

(4.6

)

851

    Corporate and financial companies  

1,239

   

1,174

   

(65

)  

(5.2

)

(14,349

)   Consolidation adjustment  

(19,594

)  

(23,445

)  

(3,851

)  

..

 

57,545

       

73,728

   

86,105

   

12,377

   

16.8

 


     

 

 

 

 

Eni's net sales from operations (revenues) for 2006 were euro 86,105 million, up euro 12,377 million from 2005, or 16.8%, primarily reflecting higher product prices in all of Eni's main operating segments, higher volumes sold of hydrocarbons and natural gas and higher activity levels in the Engineering & Construction division, offset in part by the negative impact of the appreciation of the euro versus the dollar (up 1%).

Revenues generated by the Exploration & Production division were euro 27,173 million, up euro 4,642 million, or 20.6%, primarily reflecting higher realizations in dollars (oil up 22.4%, natural gas up 17.8%) and higher oil and gas production sold (up 10.2 mmboe). These positives were partially offset by the appreciation of the euro over the dollar.

Revenues generated by the Gas & Power division were euro 28,368 million, up euro 5,399 million, or 23.5%, primarily reflecting increased natural gas prices related in
  particular to a favorable trading environment, higher natural gas volumes sold by consolidated subsidiaries (up 3.14 bcm, or 3.8%) and higher electricity production sold (up 2.05 TWh, or 9%).

Revenues generated by the Refining & Marketing division were euro 38,210 million, up euro 4,478 million, or 13.3%, primarily reflecting higher international prices for oil and refined products.

Revenues generated by the Petrochemical division were euro 6,823 million, up euro 568 million, or 9.1%, primarily reflecting an increase in average selling prices.

Revenues generated by the Engineering & Construction division were euro 6,979 million, up euro 1,246 million, or 21.7%, primarily reflecting higher activity levels in the Offshore and Onshore construction businesses and a higher utilization rate of vessels and higher tariffs in the Offshore Drilling area.

Other income and revenues
The analysis of Other income and revenues is shown in the table below:

2004   (million euro)   2005   2006   Change

     
 
 

407

    Gains on divestments of tangible and intangible assets  

71

   

100

   

29

 

93

    Income from rentals  

102

   

98

   

(4

)

43

    Income from contractual obligations  

114

   

61

   

(53

)

87

    Income from damage payments  

89

   

40

   

(49

)

61

    Gains on commodity derivative financial contracts                  

686

    Other income (*)  

422

   

484

   

62

 

1,377

       

798

   

783

   

(15

)


     

 

 

     
(*)   Each amount in this line item is less than euro 25 million.

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Operating expenses

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

38,347

    Purchases, services and other  

48,567

   

57,490

   

8,923

   

18.4

 
      of which:                        

5

    - non-recurring items  

290

   

239

   

(51

)      

298

    - other special items  

1,300

   

390

   

(910

)      

3,245

    Payroll and related costs  

3,351

   

3,650

   

299

   

8.9

 
      of which:                        

65

    - provision for redundancy incentives  

79

   

178

   

99

       

41,592

       

51,918

   

61,140

   

9,222

   

17.8

 


     

 

 

 

 

Operating expenses for 2006 (euro 61,140 million) were up euro 9,222 million from 2005, or 17.8%, reflecting primarily: (i) higher prices for oil-based and petrochemical feedstocks and for natural gas, affected also by higher charges related to the climatic emergency of the first quarter of 2006; (ii) higher operating costs in the Exploration & Production division, in particular the increase in operating costs resulted from the higher share of development projects in hostile environments and reflected sector-specific inflation; (iii) higher costs for refinery maintenance. These negative factors were offset in part by the impact of the appreciation of the euro over the dollar.
Operating expenses include non recurring charges of euro 239 million in 2006 related essentially to a provision related to fines imposed by certain antitrust and regulatory authorities; in 2005 non-recurring charges of euro 290 million concerned a provision related to a fine levied by the Italian Antitrust Authority.
  Other special charges included in operating costs in 2006 (euro 390 million) related to environmental provisions (euro 292 million), in particular in Syndial and in the Refining & Marketing division; in 2005 other special items of euro 1,300 million concerned essentially environmental provisions (euro 835 million) recorded in particular in Syndial and in the Refining & Marketing division, and provisions to the risk reserve (euro 379 million) related in particular to insurance charges deriving from the extra premium due for 2005 and for the next five years (assuming normal accident rates) related to the participation of Eni to Oil Insurance Ltd. These higher charges took account of the exceptionally high rate of accidents which occurred in the 2004-2005 two year period.
Labor costs (euro 3,650 million) were up euro 299 million, or 8.9%, reflecting primarily higher redundancy incentives (up euro 99 million), ordinary wage trends and higher average workforce outside Italy, in particular in the Engineering & Construction division, partly offset by a reduction in average workforce in Italy.

Depreciation, amortization and impairments

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

3,047

    Exploration & Production  

3,945

   

4,646

   

701

   

17.8

 

637

    Gas & Power  

684

   

687

   

3

   

0.4

 

465

    Refining & Marketing  

462

   

434

   

(28

)  

(6.1

)

114

    Petrochemical  

118

   

124

   

6

   

5.1

 

184

    Engineering & Construction  

176

   

195

   

19

   

10.8

 

45

    Other activities  

16

   

6

   

(10

)  

(62.5

)

106

    Corporate and financial companies  

112

   

70

   

(42

)  

(37.5

)
      Unrealized profit in inventory  

(4

)  

(9

)  

(5

)  

..

 

4,598

    Total depreciation and amortization  

5,509

   

6,153

   

644

   

11.7

 

333

    Impairments  

272

   

268

   

(4

)  

(1.5

)

4,931

       

5,781

   

6,421

   

640

   

11.1

 


     

 

 

 

 

In 2006 depreciation and amortization charges (euro 6,153 million) were up euro 644 million, or 11.7%, from 2005 mainly in the Exploration & Production division (euro 701 million) reflecting primarily higher exploration expenditure and   increased development costs incurred for developing new fields and maintaining production levels in mature fields combined with the effects of higher production.

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Impairments (euro 268 million) concerned essentially mineral assets in the Exploration & Production division,   intangible assets in the Gas & Power division and tangible assets in the Petrochemical division.

Operating profit

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

12,399

    Operating profit  

16,827

   

19,327

   

2,500

   

14.9

 

(448

)   Exclusion of inventory holding (gains) losses  

(1,210

)  

88

   

1,298

       

631

    Exclusion of special items:  

1,941

   

1,075

   

(866

)      
      of which:                        

5

    - non-recurring items  

290

   

239

   

(51

)      

626

    - other special items  

1,651

   

836

   

(815

)      

12,582

    Adjusted operating profit  

17,558

   

20,490

   

2,932

   

16.7

 
                               
      Break-down by division:                        

8,202

    Exploration & Production  

12,903

   

15,763

   

2,860

   

22.2

 

3,448

    Gas & Power  

3,531

   

3,882

   

351

   

9.9

 

923

    Refining & Marketing  

1,214

   

790

   

(424

)  

(34.9

)

263

    Petrochemicals  

261

   

219

   

(42

)  

(16.1

)

215

    Engineering & Construction  

314

   

508

   

194

   

61.8

 

(223

)   Other activities  

(296

)  

(299

)  

(3

)  

(1.0

)

(187

)   Corporate and financial companies  

(228

)  

(240

)  

(12

)  

(5.3

)

(59

)   Unrealized profit in inventory  

(141

)  

(133

)  

8

   

..

 

12,582

       

17,558

   

20,490

   

2,932

   

16.7

 


     

 

 

 

 

Adjusted operating profit, excluding an inventory holding loss of euro 88 million and special charges of euro 1,075 million, amounted to euro 20,490 million, an increase of euro 2,932 million from 2005 (up 16.7%), related in particular to: (i) the Exploration & Production division (up euro 2,860 million, or 22.2%), reflecting higher realizations and higher production sold (up 10.2 mmboe, or 1.7%), partly offset by higher operating costs and amortization charges and increased exploration expenses; (ii) the Gas & Power division (up euro 351 million, or 9.9%) due to higher natural gas selling   margins, a softer impact of Resolution No. 248/2004 of the Authority for Electricity and Gas and higher sales of consolidated companies (up 3.14 bcm, or 3.8%); (iii) the Engineering & Construction division (up euro 194 million, or 61.8%) due to a positive performance against the backdrop of favorable oil services markets.
These increases were offset in part by the decline of the Refining & Marketing division (down euro 424 million, or 34.9%) due to a negative refining trading environment and the impact of longer standstills of refineries due to planned maintenance.

Net financial income

    (million euro)   2005   2006   Change
       
 
 
Income (expense) on derivatives   (386 )   383     769  
Exchange differences, net   169     (152 )   (321 )
Net interest due to banks   60     194     134  
Financial expense on short and long-term debt   (420 )   (462 )   (42 )
Financial expense due to the passage of time   (109 )   (116 )   (7 )
Other financial income and expense, net   161     198     37  
    (525 )   45     570  
Financial expense capitalized   159     116     (43 )
    (366 )   161     527  
   

 

 

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2006 net financial income (euro 161 billion) was up euro 527 million from 2005 when net financial charges of euro 366 were recorded. The increase reflected: (i) the positive change in the fair value evaluation of financial derivative instruments recorded in the profit and loss account instead of being recognized in connection with related assets, liabilities and commitments because   Eni's financial derivative instruments do not meet the formal criteria to be assessed as hedging instruments under IFRS; (ii) higher interest income deriving from a higher average availability of cash and cash equivalents offset in part by the impact of higher interest rates on dollar loans (Libor up 1.7 percentage points) and on euro loans (Euribor up 0.9 percentage points).

Net income from investments
The table below sets forth 2006 break-down of net income from investments by division:

  (million euro)   Exploration & Production   Gas & Power   Refining & Marketing   Engineering & Construction   Group
     
 
 
 
 
Effect of the application of the equity method of accounting   28     509     194     66     795  
Dividends   68     3     26           98  
Net gains on disposal   (6 )   21                 18  
Other income (losses) from investments   (5 )   (7 )               (8 )
    85     526     220     66     903  
   

 

 

 

 

 

Net income from investments in 2006 were euro 903 million and concerned primarily: (i) Eni's share of income of affiliates accounted for with the equity method (euro 795 million), in particular affiliates in the Gas & Power and Refining & Marketing divisions. The effects of the equity method of accounting include the gain   (euro 73 million net to Eni) recorded by Galp Energia SGPS SA on the sale of regulated assets in the natural gas business to Rede Eléctrica Nacional, classified as special; (ii) dividends received by affiliates accounted for at cost (euro 98 million, of which euro 57 million related to Nigeria LNG); (iii) net gains on disposal (euro 18 million).

The comparison with 2005 data is shown in the table below:

2004   (million euro)   2005   2006   Change

     
 
 
332     Effect of the application of the equity method of accounting   737     795     58  
72     Dividends   33     98     65  
129     Net gains on disposal   171     18     (153 )
287     Other income (losses) from investments   (27 )   (8 )   19  
820         914     903     (11 )


     

 

 

 

The euro 11 million decrease in net income from investments from 2005 was due essentially to lower gains related in particular to the recording in 2005 of the gain on the sale of Italiana Petroli SpA (euro 132 million), whose effects were offset in part by improved   results of operations of affiliates in the Gas & Power division, in particular Unión Fenosa Gas SA and Blue Stream Pipeline Co BV and higher dividends distributed by Nigeria LNG.

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Income taxes

    (million euro)   2005   2006   Change
       
 
 
Profit before income taxes                  
Italy   5,779     5,566     (213 )
Outside Italy   11,596     14,825     3,229  
    17,375     20,391     3,016  
Income taxes                  
Italy   2,206     2,237     31  
Outside Italy   5,922     8,331     2,409  
    8,128     10,568     2,440  
Tax rate (%)                  
Italy   38.2     40.2     2.0  
Outside Italy   51.1     56.2     5.1  
    46.8     51.8     5.0  
   

 

 

 

Income taxes were euro 10,568 million, up euro 2,440 million from 2005 and reflected primarily higher income before taxes (euro 3,016 million). The 5 percentage point increase in statutory tax rate (from 46.8 to 51.8%) related mainly to: (i) the introduction of a windfall tax on upstream earnings in Algeria effective as from August 1, 2006 (with an overall impact of euro 328 million, of which euro 149 million pertaining to taxation for the period and euro 179 million pertaining to the deferred tax impact); (ii) an increase in the supplemental tax rate implemented by the British Government, applicable to profit before taxes earned by operations in the North Sea, effective as from the   beginning of the year, affecting both current taxation and deferred tax (with an overall impact of euro 198 million, of which euro 107 million pertaining to taxation for the period and euro 91 million pertaining to the deferred tax impact); (iii) provisions for the settlement of a tax claim in Venezuela. Adjusted tax rate, which is calculated by excluding special charges, was 48.7% (46% in 2005).

Minority interest
Minority interest
were euro 606 million and concerned primarily Snam Rete Gas SpA (euro 287 million) and Saipem (euro 311 million).

Divisional performance

Exploration & Production

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

8,185

    Operating profit  

12,592

   

15,580

   

2,988

   

23.7

 

17

    Exclusion of special items:  

311

   

183

   

(128

)      

287

    - asset impairments  

247

   

231

   

(16

)      

(320

)   - gains on disposal of assets        

(61

)  

(61

)      

2

    - provision for redundancy incentives  

7

   

13

   

6

       

29

    - provision to the reserve for contingencies  

57

         

(57

)      

19

    - other                        

8,202

    Adjusted operating profit  

12,903

   

15,763

   

2,860

   

22.2

 

(85

)   Net financial expense (a)  

(80

)  

(59

)  

21

       

9

    Net income from investments (a)  

10

   

85

   

75

       

(4,093

)   Income taxes (a)  

(6,647

)  

(8,510

)  

(1,863

)      

50.4

    Tax rate (%)  

51.8

   

53.9

   

2.1

       

4,033

    Adjusted net profit  

6,186

   

7,279

   

1,093

   

17.7

 
      Results also include:                        

3,334

    - amortizations and depreciations  

4,101

   

4,776

   

675

   

16.5

 

563

    - of which amortizations of exploration expenditure  

618

   

1,075

   

457

   

73.9

 


     

 

 

 

     
(a)   Excludes special items.

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The adjusted operating profit for the year was euro 15,763 million, up euro 2,860 million from one year ago, reflecting higher realizations in dollars (oil up 22.4%, natural gas up 17.8) combined with higher sold production volumes (up 10.2 mmboe or 1.7%).
This enhanced operating performance was partly offset by: (i) increased production costs and amortization charges related in particular to the higher cost of developing new fields and maintaining production levels at mature fields and sector specific inflation; (ii) an increased exploration expense; (iii) the effect of the appreciation of the euro over the dollar (approximately euro 155 million).
  This enhanced operating performance was partly offset by an increase in the adjusted tax rate (up 2.1% from 51.8% to 53.9%), resulting in a euro 1.093 million increase (or 17.7%) in the adjusted net profit for the year.
Special charges excluded from the adjusted operating profit were euro 183 million and reflected mineral asset impairments offset in part by gains on the disposal of mineral assets. Special charges excluded from the adjusted net profit also include the deferred tax impact of the windfall tax in Algeria, the supplemental tax rate applicable to profit earned in the North Sea enacted by the British Government and a charge for the settlement of a taxation proceeding against a Venezuelan authority for a combined amount of euro 342 million.

Gas & Power

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

3,428

    Operating profit  

3,321

   

3,802

   

481

   

14.5

 

(12

)   Exclusion of inventory holding (gains) losses  

(127

)  

(67

)  

60

       

32

    Exclusion of special items  

337

   

147

   

(190

)      

5

    of which: non-recurring items  

290

   

55

   

(235

)      

27

    Other special items  

47

   

92

   

45

       

6

    - asset impairments  

1

   

51

   

50

       

5

    - environmental provisions  

31

   

44

   

13

       

10

    - provisions for redundancy incentives  

8

   

37

   

29

       

18

    - provision to the reserve for contingencies  

6

         

(6

)      

(12

)   - other  

1

   

(40

)  

(41

)      

3,448

    Adjusted operating profit  

3,531

   

3,882

   

351

   

9.9

 

1,827

    Market and Distribution  

1,777

   

2,062

   

285

   

16.0

 

1,164

    Transport in Italy  

1,162

   

1,087

   

(75

)  

(6.5

)

396

    Transport outside Italy  

448

   

579

   

131

   

29.2

 

61

    Power generation  

144

   

154

   

10

   

6.9

 

31

    Net financial expense (a)  

37

   

16

   

(21

)      

215

    Net income from investments (a)  

370

   

489

   

119

       

(1,404

)   Income taxes (a)  

(1,386

)  

(1,525

)  

(139

)      

38.0

    Tax rate (%)  

35.2

   

34.8

   

(0.4

)      

2,290

    Adjusted net profit  

2,552

   

2,862

   

310

   

12.1

 


     

 

 

 

     
(a)   Excludes special items.

 

The adjusted operating profit of the Gas & Power division rose by euro 351 million or 9.9% to euro 3,882 million, primarily reflecting: (i) higher selling margins on natural gas against the backdrop of a favorable trading environment; (ii) a lower impact of the tariff regime implemented by the Authority for Electricity and Gas with Resolution No. 248/2004; (iii) a growth in natural gas sales by consolidated subsidiaries (up 3.14   bcm, or 3.8%), in volumes transported outside Italy due to the coming on line of volumes transported through the Greenstream gasline from Libya, and in electricity production sold (up 2.05 TWh, or 9%). These positives were partly offset by a lower operating result from transportation activities in Italy due to the tariff regime enacted by the Authority for Electricity and Gas with Resolution No. 166/2005 and a lower operating result

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from distribution activities due to lower volumes.
In addition, higher purchase costs were incurred in the first quarter of the year, owing to a climatic emergency.
Full year adjusted net profit of euro 2,862 million increased by euro 310 million from 2005 (up 12.1%) and also benefited from the improved performance of certain equity-accounted entities.
Special charges for the full year recorded in the operating profit (euro 147 million) included certain non recurring
  charges pertaining to fines imposed by the Authority for Electricity and Gas, and impairments of certain intangible assets, environmental charges and provisions for redundancy incentives. Special charges excluded from the adjusted net profit also include Eni's share of a gain recorded by the equity-accounted Galp on the sale of certain regulated gas assets.

Refining & Marketing

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

1,080

    Operating profit  

1,857

   

319

   

(1,538

)  

(82.8

)

(393

)   Exclusion of inventory holding (gains) losses  

(1,064

)  

215

   

1,279

       

236

    Exclusion of special items  

421

   

256

   

(165

)      
      of which: non-recurring items        

109

   

109

       

236

    Other special items  

421

   

147

   

(274

)      

21

    - impairments  

5

   

14

   

9

       

142

    - environmental charges  

337

   

111

   

(226

)      

20

    - provision for redundancy incentives  

22

   

47

   

25

       

77

    - provision to the reserve for contingencies  

39

   

8

   

(31

)      
      - increase insurance charges  

30

         

(30

)      

(24

)   - other  

(12

)  

(33

)  

(21

)      

923

    Adjusted operating profit  

1,214

   

790

   

(424

)  

(34.9

)

5

    Net financial expense (a)                        

96

    Net income from investments (a)  

231

   

184

   

(47

)      

(350

)   Income taxes (a)  

(500

)  

(345

)  

155

       

34.2

    Tax rate (%)  

35.6

   

35.4

   

0.8

       

674

    Adjusted net profit  

945

   

629

   

(316

)  

(33.4

)


     

 

 

 

     
(a)   Excludes special items.

 

The adjusted operating profit for 2006 was euro 790 million, down euro 424 million, or 34.9%, from 2005 reflecting primarily: (i) lower realized refining margins reflecting the unfavorable trading environment and the appreciation of the euro versus the dollar, combined with the impact of longer refinery standstills due to planned maintenance partly offset by the higher profitability of processed crudes; (ii) a decline in the operating performance of Italian marketing activities due to lower volumes sold which were negatively affected by the mild weather conditions registered in the fourth quarter and the   divestment of Italiana Petroli carried out in September 2005. On the positive side, marketing activities in the rest of Europe performed well as a result of higher retail margins and higher volumes sold.
The adjusted net profit for 2006 was euro 629 million, down euro 316 million, or 33.4%, from 2005, reflecting primarily a decrease in operating profit.
Special charges excluded from the adjusted operating profit were euro 256 million, reflecting primarily the impact of a non-recurring charge related to a fine imposed by the Italian Antitrust Authority, and environmental provisions and provisions for redundancy incentives.

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Petrochemical

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

320

    Operating profit  

202

   

172

   

(30

)  

(14.9

)

(43

)   Exclusion of inventory holding (gains) losses  

(19

)  

(60

)  

(41

)      

(14

)   Exclusion of special items  

78

   

107

   

29

       
      of which: non-recurring items        

13

   

13

       

(14

)   Other special items  

78

   

94

   

16

       

3

    - impairments  

29

   

50

   

21

       

6

    - provision for redudancy incentives  

4

   

19

   

15

       

3

    - provision to the reserve for contingencies  

36

   

31

   

(5

)      
      - increase insurance charges  

17

         

(17

)      

(26

)   - other  

(8

)  

(6

)  

2

       

263

    Adjusted operating profit  

261

   

219

   

(42

)  

(16.1

)

2

    Net income from investments (a)  

3

   

2

   

(1

)      

(23

)   Income taxes (a)  

(37

)  

(47

)  

(10

)      

242

    Adjusted net profit  

227

   

174

   

(53

)  

(23.3

)


     

 

 

 

     
(a)   Excludes special items.

 

Adjusted operating profit was euro 219 million, down euro 42 million, or 16.1%, from a year ago, due to lower selling margins on products recorded in the first half of the year. This decline affected all businesses with the exception of polyethylene, owing to increases in the cost of oil-based feedstocks not transferred to selling prices. Results for the year were also negatively impacted by the accident occurred at the Priolo refinery in April resulting in lower   product availability. These negative factors were offset in part by the positive effect of Eni's sales mix along with an improved industrial and commercial performance.
Special charges excluded from the adjusted operating profit were euro 107 million, reflecting primarily asset impairments, the impact of a non-recurring charge related to a fine imposed by an European antitrust authority, and provisions for risks and redundancy incentives.

Engineering & Construction

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

203

    Operating profit  

307

   

505

   

198

   

64.5

 

12

    Exclusion of special items:  

7

   

3

   

(4

)      

10

    - provision for redudancy incentives  

3

   

2

   

(1

)      
      - impairments  

4

   

1

   

(3

)      

1

    - provision to the reserve for contingencies                        

1

    - other                        

215

    Adjusted operating profit  

314

   

508

   

194

   

61.8

 

118

    Net income from investments (a)  

141

   

66

   

(75

)      

(81

)   Income taxes (a)  

(127

)  

(174

)  

(47

)      

252

    Adjusted net profit  

328

   

400

   

72

   

22.0

 


     

 

 

 

     
(a)   Excludes special items.

 

Adjusted operating profit for 2006 was euro 508 million, up euro 194 million (up 61.8%) from 2005.
This increase was recorded in particular in the following areas: (i) Offshore, due to higher activity in the Caspian region and Nigeria; (ii) Offshore Drilling, due to higher tariffs for the Scarabeo 3 and Scarabeo 5 semi-submersible platforms and higher activity levels
  of the Perro Negro 5 jack-up and Scarabeo 4 semi-submersible platform; (iii) Onshore due to higher activity related essentially to the start-up of some large projects acquired in 2005.
Adjusted net profit of euro 400 million increased by euro 72 million from 2005 (up 22%) due to an enhanced operating performance, offset in part by losses of affiliates.

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Other activities

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

(395

)   Operating profit  

(934

)  

(622

)  

312

   

33.4

 

172

    Exclusion of special items  

638

   

323

   

(315

)      
      of which: non-recurring items        

62

   

62

       

172

    Other special items  

638

   

261

   

(377

)      

84

    - environmental charges  

413

   

126

   

(287

)      

15

    - provision to the reserve for contingencies  

130

   

75

   

(55

)      

19

    - impairments  

75

   

22

   

(53

)      

6

    - provision for redudancy incentives  

6

   

17

   

11

       

48

    - other  

14

   

21

   

7

       

(223

)   Adjusted operating profit  

(296

)  

(299

)  

(3

)  

(1.0

)
      Net financial expense (a)        

(7

)  

(7

)      

4

    Net income from investments (a)  

(1

)  

5

   

6

       

(22

)   Income taxes (a)                        

(241

)   Adjusted net profit  

(297

)  

(301

)  

(4

)  

(1.3

)


     

 

 

 

     
(a)   Excludes special items.

 

In 2006 Syndial reported an adjusted operating loss of euro 299 million, in line with the previous year.
Special charges excluded from the adjusted operating profit totalled euro 323 million (euro 638 million in 2005),
  reflecting primarily environmental charges and provisions for risks, and the impact of a non-recurring charge related to a fine imposed by the European antitrust authority.

Corporate and financial companies

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 

(363

)   Operating profit  

(377

)  

(296

)  

81

   

21.5

 

176

    Exclusion of special items:  

149

   

56

   

(93

)      

11

    - provision for redudancy incentives  

29

   

43

   

14

       

91

    - provision to the reserve for contingencies  

64

   

11

   

(53

)      

72

    - environmental charges  

54

         

(54

)      
      - impairments  

2

         

(2

)      

2

    - other        

2

             

(187

)   Adjusted operating profit  

(228

)  

(240

)  

(12

)  

(5.3

)

(107

)   Net financial expense (a)  

(296

)  

205

   

501

       

(14

)   Net income from investments (a)  

23

         

(23

)      

222

    Income taxes (a)  

359

   

89

   

(270

)      

(86

)   Adjusted net profit  

(142

)  

54

   

196

   

..

 


     

 

 

 

     
(a)   Excludes special items.

 

The aggregate Corporate and financial companies reported an adjusted operating loss of euro 240 million (euro 228 million in 2005) which excludes special charges of euro 56 million (euro 149 million in 2005) related mainly to provision for redundancy incentives.   Adjusted net profit of euro 54 million increased by euro 196 million from 2005 due to a better financing performance reflecting the positive change in the fair value evaluation of financial derivative instruments and higher interest income deriving from a higher average availability of cash and cash equivalents.

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NON-GAAP Measures

Reconciliation of reported operating profit and net profit to results on an adjusted basis

Management evaluates Group and business performance on the basis of adjusted operating profit and adjusted net profit, which are arrived at by excluding inventory holding gains or losses and special items. Further, finance charges on finance debt, interest income, charges or income deriving from the fair value evaluation of derivative financial instruments held for trading purposes, and exchange rate differences are excluded when determining adjusted net profit of each business segment.

Taxation effect of such items excluded from adjusted net profit is determined based on the specific rate of taxes applicable to each item, with the exception of finance charges or income, to which the Italian statutory tax rate of 33% is applied.

Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or U.S. GAAP. Management includes them to facilitate comparison of base business performance across periods and allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models. In addition, management uses segmental adjusted net profit when calculating return on average capital employed (ROACE) by each business segment.

The following is a description of items which are excluded from the calculation of adjusted results.

Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold in the period calculated using the weighted-average cost method of inventory accounting.

Special items include certain relevant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-recurring items under such circumstances; or (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past exercises or are likely to occur in future ones. As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. In addition the effect of the fair value evaluation of derivative financial instruments held for trading purposes and exchange rate differences are excluded from the adjusted net profit of business segments. Therefore, the adjusted net profit of business segments includes finance charges or income deriving from certain segment-operated assets, i.e., interest income on certain receivable financing and securities related to operations and finance charges pertaining to the accretion of certain provisions recorded on a discounted basis (as in the case of asset retirement obligations in the Exploration and Production division).

Finance charges or interest income and related taxation effects, excluded from the adjusted net profit of the business segments are allocated on the aggregate Corporate and financial companies.

For a reconciliation of adjusted operating profit and adjusted net profit to reported operating profit and net profit see tables below.

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2006

(million euro)   E&P   G&P   R&M   Petrochemical   E&C   Other activities   Corporate and financial companies   Unrealized profit in inventory   Group
   
 
 
 
 
 
 
 
 
Reported operating profit  

15,580

   

3,802

   

319

   

172

   

505

   

(622

)  

(296

)  

(133

)  

19,327

 
Exclusion of inventory holding (gains) losses        

(67

)  

215

   

(60

)                          

88

 
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

55

   

109

   

13

         

62

               

239

 
Other special charges:  

183

   

92

   

147

   

94

   

3

   

261

   

56

         

836

 
     environmental charges        

44

   

111

               

126

   

11

         

292

 
     asset impairments  

231

   

51

   

14

   

50

   

1

   

22

               

369

 
     gains on disposal of assets  

(61

)                                            

(61

)
     provisions to the reserve for contingencies              

8

   

31

         

75

               

114

 
     provision for redundancy incentives  

13

   

37

   

47

   

19

   

2

   

17

   

43

         

178

 
     other        

(40

)  

(33

)  

(6

)        

21

   

2

         

(56

)
Special items of operating profit  

183

   

147

   

256

   

107

   

3

   

323

   

56

         

1,075

 
Adjusted operating profit  

15,763

   

3,882

   

790

   

219

   

508

   

(299

)  

(240

)  

(133

)  

20,490

 
Net financial (expense) income (*)  

(59

)  

16

                     

(7

)  

205

         

155

 
Net income from investments (*)  

85

   

489

   

184

   

2

   

66

   

5

               

831

 
Income taxes (*)  

(8,510

)  

(1,525

)  

(345

)  

(47

)  

(174

)        

89

   

54

   

(10,458

)
Tax rate (%)  

53.9

   

34.8

   

35.4

                                 

48.7

 
Adjusted net profit  

7,279

   

2,862

   

629

   

174

   

400

   

(301

)  

54

   

(79

)  

11,018

 
of which:                                                      
- net profit of minorities                                                  

606

 
- Eni’s adjusted net profit                                                  

10,412

 
                                                       
Eni’s reported net profit                                                  

9,217

 
Exclusion of inventory holding (gains) losses                                                  

33

 
Exclusion of special items                                                  

1,162

 
     Non-recurring (income) charges                                                  

239

 
     Other special charges                                                  

923

 
Eni’s adjusted net profit                                                  

10,412

 
   
 
 
 
 
 
 
 
 
     
(*)   Excludes special items.

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2005

(million euro)   E&P   G&P   R&M   Petrochemical   E&C   Other activities   Corporate and financial companies   Unrealized profit in inventory   Group
   
 
 
 
 
 
 
 
 
Reported operating profit  

12,592

   

3,321

   

1,857

   

202

   

307

   

(934

)  

(377

)  

(141

)  

16,827

 
Exclusion of inventory holding (gains) losses        

(127

)  

(1,064

)  

(19

)                          

(1,210

)
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

290

                                       

290

 
Other special charges:  

311

   

47

   

421

   

78

   

7

   

638

   

149

         

1,651

 
     environmental charges        

31

   

337

               

413

   

54

         

835

 
     asset impairments  

247

   

1

   

5

   

29

   

4

   

75

   

2

         

363

 
     provisions to the reserve for contingencies              

39

   

36

         

126

               

201

 
     increase insurance charges  

57

   

6

   

30

   

17

         

4

   

64

         

178

 
     provision for redundancy incentives  

7

   

8

   

22

   

4

   

3

   

6

   

29

         

79

 
     other        

1

   

(12

)  

(8

)        

14

               

(5

)
Special items of operating profit  

311

   

337

   

421

   

78

   

7

   

638

   

149

         

1,941

 
Adjusted operating profit  

12,903

   

3,531

   

1,214

   

261

   

314

   

(296

)  

(228

)  

(141

)  

17,558

 
Net financial (expense) income (*)  

(80

)  

37

                           

(296

)        

(339

)
Net income from investments (*)  

10

   

370

   

231

   

3

   

141

   

(1

)  

23

         

777

 
Income taxes (*)  

(6,647

)  

(1,386

)  

(500

)  

(37

)  

(127

)        

359

   

52

   

(8,286

)
Tax rate (%)  

51.8

   

35.2

   

34.6

                                 

46.0

 
Adjusted net profit  

6,186

   

2,552

   

945

   

227

   

328

   

(297

)  

(142

)  

(89

)  

9,710

 
of which:                                                      
- net profit of minorities                                                  

459

 
- Eni’s adjusted net profit                                                  

9,251

 
                                                       
Eni’s reported net profit                                                  

8,788

 
Exclusion of inventory holding (gains) losses                                                  

(759

)
Exclusion of special items                                                  

1,222

 
     Non-recurring (income) charges                                                  

290

 
     Other special charges                                                  

932

 
Eni’s adjusted net profit                                                  

9,251

 
   
 
 
 
 
 
 
 
 
     
(*)   Excludes special items.

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2004

(million euro)   E&P   G&P   R&M   Petrochemical   E&C   Other activities   Corporate and financial companies   Unrealized profit in inventory   Group
   
 
 
 
 
 
 
 
 
Reported operating profit  

8,185

   

3,428

   

1,080

   

320

   

203

   

(395

)  

(346

)  

(59

)  

12,399

 
Exclusion of inventory holding (gains) losses        

(12

)  

(393

)  

(43

)                          

(448

)
Exclusion of special items                                                      
of which:                                                      
Non-recurring (income) charges        

5

                                       

5

 
Other special charges:  

17

   

27

   

236

   

(14

)  

12

   

172

   

176

         

626

 
     environmental charges        

5

   

142

               

84

   

72

         

303

 
     asset impairments  

287

   

6

   

21

   

3

         

19

               

336

 
     gains on disposal of assets  

(320

)                                            

(320

)
     provisions to the reserve for contingencies  

29

   

18

   

77

   

3

   

1

   

15

               

143

 
     increase insurance charges                                      

91

         

91

 
     provision for redundancy incentives  

2

   

10

   

20

   

6

   

10

   

6

   

11

         

65

 
     other  

19

   

(12

)  

(24

)  

(26

)  

1

   

48

   

2

         

8

 
Special items of operating profit  

17

   

32

   

236

   

(14

)  

12

   

172

   

176

         

631

 
Adjusted operating profit  

8,202

   

3,448

   

923

   

263

   

215

   

(223

)  

(187

)  

(59

)  

12,582

 
Net financial (expense) income (*)  

(85

)  

31

   

5

                     

(107

)        

(156

)
Net income from investments (*)  

9

   

215

   

96

   

2

   

118

   

4

   

(14

)        

430

 
Income taxes (*)  

4,093

   

(1,404

)  

(350

)  

(23

)  

(81

)  

(22

)  

222

   

22

   

(5,729

)
Tax rate (%)  

50.4

   

38.0

   

34.2

                                 

44.6

 
Adjusted net profit  

4,033

   

2,290

   

674

   

242

   

252

   

(241

)  

(88

)  

(37

)  

7,127

 
of which:                                                      
- net profit of minorities                                                  

482

 
- Eni’s adjusted net profit                                                  

6,645

 
                                                       
Eni’s reported net profit                                                  

7,059

 
Exclusion of inventory holding (gains) losses                                                  

(281

)
Exclusion of special items                                                  

(133

)
     Non-recurring (income) charges                                                  

5

 
     Other special charges                                                  

(138

)
Eni’s adjusted net profit                                                  

6,645

 
   
 
 
 
 
 
 
 
 
     
(*)   Excludes special items.

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Analysis of special items

2004   (million euro)   2005   2006   Change

     
 
 
5     Non-recurring (income) charges   290     239     (51 )
626     Other special charges:   1,651     836     (815 )
303     environmental charges   835     292     (543 )
336     asset impairments   363     369     6  
(320 )   gains on disposal of assets         (61 )   (61 )
234     provisions to the reserve for contingencies   379     114     (265 )
      of which:                  
91     increase insurance charges   178           (178 )
65     provisions for redundancy incentives   79     178     99  
8     other   (5 )   (56 )   (51 )
631     Special items of operating profit   1,941     1,075     (866 )
      Net financial (expense) income   27     (6 )   (33 )
(390 )   Net income from investments   (137 )   (72 )   65  
      of which:                  
      gain on the disposal of Italiana Petroli (IP)   (132 )         132  
      gain on Galp Energia SGPS SA (disposal assets Rede Electrica National)         (73 )   (73 )
(308 )   gain on the disposal of shares of Snam Rete Gas SpA                  
(374 )   Income taxes   (609 )   165     774  
      of which:                  
      supplemental tax rate UK         91     91  
      windfall tax Algeria         179     179  
      legal proceeding in Venezuela         77     77  
(133 )   Total special items of net profit   1,222     1,162     (60 )


     

 

 

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Summarized Group Balance Sheet

Summarized group balance sheet aggregates the amount of assets and liabilities derived from the statutory balance sheet in accordance with functional criteria which consider the enterprise conventionally divided into the three fundamental areas focusing on resource investments, operations and financing. Management believes that this summarized group balance sheet is useful information in assisting investors   to assess Eni's capital structure and to analyze its sources of funds and investments in fixed assets and working capital. Management uses the summarized group balance sheet to calculate key ratios such as return on capital employed (ROACE) and the proportion of net borrowings to shareholders' equity (leverage) intended to evaluate whether Eni's financing structure is sound and well-balanced.

Summarized Group Balance Sheet (a)

(million euro)  

Dec. 31, 2005

 

Sep. 30, 2006

 

Dec. 31, 2006

 

Change vs Dec. 31, 2005

 

Change vs
Sep. 30, 2006

   
 
 
 
 
Fixed assets                              
Property, plant and equipment, net   45,013     43,408     44,312     (701 )   904  
Other tangible assets         656     629     629     (27 )
Inventories - compulsory stock   2,194     1,962     1,827     (367 )   (135 )
Intangible assets, net   3,194     3,285     3,753     559     468  
Investments, net   4,311     4,234     4,246     (65 )   12  
Accounts receivable financing and securities related to operations   775     640     557     (218 )   (83 )
Net accounts payable in relation to capital expenditure   (1,196 )   (912 )   (1,090 )   106     (178 )
    54,291     53,273     54,234     (57 )   961  
Net working capital                              
Inventories   3,563     4,440     4,752     1,189     312  
Trade accounts receivable   14,101     12,858     15,230     1,129     2,372  
Trade accounts payable   (8,170 )   (8,136 )   (10,528 )   (2,358 )   (2,392 )
Taxes payable and reserve for net deferred income tax liabilities   (4,857 )   (6,867 )   (5,396 )   (539 )   1,471  
Reserve for contingencies   (7,679 )   (7,741 )   (8,614 )   (935 )   (873 )
Other operating assets and liabilities (b)   (526 )   (553 )   (641 )   (115 )   (88 )
    (3,568 )   (5,999 )   (5,197 )   (1,629 )   802  
Employee termination indemnities and other benefits   (1,031 )   (1,054 )   (1,071 )   (40 )   (17 )
Capital employed, net   49,692     46,220     47,966     (1,726 )   1,746  
Shareholders’ equity including minority interests   39,217     42,370     41,199     1,982     (1,171 )
Net borrowings   10,475     3,850     6,767     (3,708 )   2,917  
Total liabilities and shareholders’ equity   49,692     46,220     47,966     (1,726 )   1,746  
   

 

 

 

 

     
(a)   For a reconciliation to the statutory balance sheet see paragraph “Reconciliation of Summarized Group Balance Sheet and Statement of Cash Flows to statutory schemes” pages 77 and 78.
(b)   Include operating financing receivables and securities related to operations for euro 249 million (euro 492 million and euro 261 million at December 31, 2005 and September 30, 2006, respectively) and securities covering technical reserves of Padana Assicurazioni SpA for euro 417 million (euro 453 million and euro 550 million at December 31, 2005 and September 30, 2006, respectively).

 

The appreciation of the euro over other currencies, in particular the dollar (at December 31, 2006 the EUR/USD exchange rate was 1.317 as compared to 1.180 at December 31, 2005, up 11.6%) determined with respect to year-end 2006, an estimated decrease in the book value of net capital employed of approximately euro 2,200 million, in net equity of approximately euro 1,550 million and in net borrowings of approximately euro 650 million as a result of currency conversions at December 31, 2006.   At December 31, 2006, net capital employed totaled euro 47,966 million, representing a decrease of euro 1,726 million from December 31, 2005.
Fixed assets (euro 54,234 million) are substantially in line with December 31, 2005 (euro 54,291 million). Provisions for depreciation, amortization and impairments (euro 6,421 million) and the effect of the appreciation of the euro over the dollar in the translation of financial statements of subsidiaries operating with currencies other than the euro (euro 2,200 million) offset capital expenditure for the

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period (euro 7,833 million). Property, plant and equipment (euro 44,312 million) were primarily related to the Exploration & Production (51.9%), Gas & Power (31.7%) and Refining & Marketing (8.6%) segments. Provisions for depreciation, amortization and writedowns (euro 49,143 million) represented 52.6% of gross property, plant and equipment (50.4% at December 31, 2005).
Other assets included, for a book value of $829 million (corresponding to euro 629 million at the year end EUR/USD exchange rate), the assets related to the service contract for mining activities in the Dación area of the Venezuelan branch of Eni's subsidiary Eni Dación BV.
With effective date April 1, 2006, the Venezuelan State oil company Petróleos de Venezuela SA (PDVSA) unilaterally terminated the Operating Service Agreement (OSA) governing activities at the Dación oil field where Eni acted as a contractor, holding a 100% working interest. As a consequence, starting on the same day, operations at the Dación oil field are conducted by PDVSA. Eni proposed to PDVSA to agree on terms in order to recover the fair value of its Dación assets. On November 2006, Eni commenced a proceeding before an International Centre for Settlement of Investment Disputes (ICSID) Tribunal (i.e. a tribunal acting under the auspices of the ICSID Convention and being competent pursuant to the Treaty) to claim its rights. In fact, a bilateral investments treaty is in place between the Netherlands and Venezuela (the “Treaty”), Despite this action, Eni is still ready to negotiate a solution with PDVSA to obtain a fair compensation for its assets. Based on the opinion of its legal consultants, Eni believes to be entitled to a compensation for such expropriation in an amount equal to the market value of the OSA before the expropriation took place. The market value of the OSA depends upon its expected profits. In accordance with established international practice, Eni has calculated the OSA’s market value using the discounted cash flow method, based on Eni’s interest in the expected future hydrocarbon production and associated capital
  expenditures and operating costs, and applying to the projected cash flow a discount rate reflecting Eni’s cost of capital as well as the specific risk of concerned activities. Independent evaluations carried out by a primary petroleum consulting firm fully support Eni’s internal evaluation. The estimated net present value of Eni’s interest in the Dación field, as calculated by Eni, is higher than the net book value of the Dación assets which consequently have not been impaired. In accordance with the ICSID Convention, a judgement by the ICSID Tribunal awarding compensation to Eni would be binding upon the parties and immediately enforceable as if it were a final judgement of a court of each of the States that have ratified the ICSID Convention. The ICSID Convention was ratified in 143 States. Accordingly, if Venezuela fails to comply with the award and to pay the compensation, Eni could take steps to enforce the award against commercial assets of the Venezuelan Government almost anywhere those may be located (subject to national law provisions on sovereign immunity).

At December 31, 2006, net working capital totaled euro 5,197 million, representing a decrease of euro 1,629 million from December 31, 2005 mainly due to: (i) an increase in taxes payable and the reserve for net deferred tax liabilities, reflecting primarily the recording of deferred tax liabilities for the period; (ii) an increase in the reserve for contingencies, due to the evaluation review of the site restoration and abandonment reserve (in particular in the Exploration & Production division), the risk provisions with respect to certain fines imposed by certain regulatory and antitrust authorities, environmental charges and provision for redundancy incentives. Commercial working capital (inventories and trade accounts receivable/payable) was substantially in line with the value recorded in 2005.
The share of the Exploration & Production, Gas & Power and Refining & Marketing divisions on net capital employed was 89.9% (90.9% at December 31, 2005).

Return On Average Capital Employed (ROACE)

Return on Average Capital Employed for the Group, on an adjusted basis is the return on Group average capital invested, calculated as the ratio between net adjusted profit before minority interests, plus net finance charges on net borrowings, less the related tax effect and net average capital employed. The tax rate applied on finance charges is the Italian statutory tax rate of 33%. The capital invested as of period-end used for the calculation of net average   capital invested is obtained by deducting inventory gains or losses as of in the period, rectified from the related tax effect. ROACE by business segment is determined as the ratio between adjusted net profit and net average capital invested pertaining to each business segment and rectifying the net capital invested as of period-end, from net inventory gains or losses (after applying the business segment specific tax rate).

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2006 (million euro)   Exploration & Production   Gas & Power   Refining & Marketing   Group
     
 
 
 
Adjusted net profit  

7,279

 

2,862

 

629

 

11,018

Exclusion of after-tax finance expenses/interest income  

-

 

-

 

-

 

46

Adjusted net profit unlevered  

7,279

 

2,862

 

629

 

11,064

Capital employed, net:                
- at the beginning of period  

20,206

 

18,978

 

5,993

 

49,692

- at the end of period  

18,590

 

18,864

 

5,766

 

47,999

Average capital employed, net  

19,398

 

18,921

 

5,880

 

48,846

ROACE (%)  

37.5

 

15.1

 

10.7

 

22.7

   
 
 
 
                 
2005 (million euro)   Exploration & Production   Gas & Power   Refining & Marketing   Group
     
 
 
 
Adjusted net profit  

6,186

 

2,552

 

945

 

9,710

Exclusion of after-tax finance expenses/interest income  

-

 

-

 

-

 

42

Adjusted net profit unlevered  

6,186

 

2,552

 

945

 

9,752

Capital employed, net:                
- at the beginning of period  

17,954

 

18,387

 

5,081

 

45,983

- at the end of period  

20,206

 

18,898

 

5,326

 

48,933

Average capital employed, net  

19,080

 

18,643

 

5,204

 

47,458

ROACE (%)  

32.4

 

13.7

 

18.2

 

20.5

   
 
 
 
                 
2004 (million euro)   Exploration & Production   Gas & Power   Refining & Marketing   Group
     
 
 
 
Adjusted net profit  

4,033

 

2,290

 

674

 

7,127

Exclusion of after-tax finance expenses/interest income  

-

 

-

 

-

 

115

Adjusted net profit unlevered  

4,033

 

2,290

 

674

 

7,242

Capital employed, net:                
- at the beginning of period  

17,635

 

18,017

 

5,536

 

45,240

- at the end of period  

17,937

 

18,383

 

4,835

 

45,724

Average capital employed, net  

17,786

 

18,200

 

5,186

 

45,482

ROACE (%)  

22.7

 

12.6

 

13.0

 

15.9

   
 
 
 

Net borrowings and leverage

Leverage is a measure of a company's level of indebtedness, calculated as the ratio between net borrowings which is calculated by excluding cash and cash equivalents and certain very liquid assets from financial debt and shareholders' equity, including minority interests. Management makes use of leverage in order to assess the soundness and efficiency of the   Group balance sheet in terms of optimal mix between net borrowings and net equity, and to carry out benchmark analysis with industry standards.
In the medium term, management plans to maintain a strong financial structure targeting a level of leverage up to 0.40.

 

(million euro)

 

Dec. 31, 2005

 

Sep. 30, 2006

 

Dec. 31, 2006

 

Change vs Dec. 31, 2005

 

Change vs
Sep. 30, 2006

   
 
 
 
 
Debts and bonds   12,998     11,006     11,699     (1,299 )   693  
Cash and cash equivalents   (1,333 )   (6,459 )   (3,985 )   (2,652 )   2,474  
Securities not related to operations   (931 )   (418 )   (552 )   379     (134 )
Non-operating financing receivables   (259 )   (279 )   (395 )   (136 )   (116 )
Net borrowings   10,475     3,850     6,767     (3,708 )   2,917  
Shareholders’ equity including minority interest   39,217     42,370     41,199     1,982     (1,171 )
Leverage   0.27     0.09     0.16     (0.11 )   0.07  
   

 

 

 

 

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Net borrowings at December 31, 2006 were euro 6,767 million, representing a decrease of euro 3,708 million from December 31, 2005 due mainly to cash inflow generated by operating activities (euro 17,001 million). Currency translation effects also contributed to the reduction in net borrowings. Debts and bonds amounted to euro 11,699 million, of which euro 4,290 million were short-term (including the portion of long-term debt due within 12 months for euro 890 million) and euro 7,409 million were long-term.   At December 31, 2006, leverage was 0.16, compared with 0.27 at December 31, 2005.
Net borrowings increased by euro 2,917 million from September 30, 2006 (euro 3,850 million) as cash inflow generated by operating activities (euro 1,780 million) partially covered the financial requirements for capital expenditure and investments amounting to euro 2,963 million, the payment of an interim dividend for fiscal year 2006 by the parent company Eni SpA (euro 2,210 million) and the repurchase of own shares for euro 105 million.

Changes in shareholders’ equity

(million euro)

Shareholders’ equity including minority interest at December 31, 2005         39,217
Net profit for the period   9,823      
Dividends to shareholders   (4,610 )    
Shares repurchased   (1,241 )    
Issue of ordinary share capital for employee share schemes   85      
Dividends paid by consolidated subsidiaries   (222 )    
Effect on equity of the shares repurchased by consolidated subsidiaries (Snam Rete Gas/Saipem)   (306 )    
Exchange differences from translation of financial statements denominated in currencies other than the euro   (1,537 )    
Other changes   (10 )    
Total changes         1,982
Shareholders’ equity including minority interest at December 31, 2006         41,199

 

Shareholders’ equity at December 31, 2006 (euro 41,199 million) was up euro 1,982 million from December 31, 2005, due primarily to net profit before minority   interest (euro 9,823 million), offset in part by the payment of Eni's 2005 dividends, the purchase of own shares and currency translation effects.

 

Summarized cash flow statement and change in net borrowings

Eni's summarized group cash flow statement derives from the statutory statement of cash flows. It allows to create a link between changes in cash and cash equivalents (deriving from the statutory cash flows statement) occurred from the beginning of period to the end of period and changes in net borrowings (deriving from the summarized cash flow statement) occurred from the beginning of period to the end of period. The measure enabling to make such a link is represented by free cash flow which is the cash in   excess of capital expenditure needs. Starting from free cash flow it is possible to determine either: (i) changes in cash and cash equivalents for the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to financing activities), shareholders' equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange differences; (ii) changes in net borrowings for the period by adding/deducting cash flows relating to shareholders' equity and the effect of changes in consolidation and of exchange differences.

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Summarized Group Cash Flow Statement (a)

2004   (million euro)   2005   2006   Change

     
 
 
7,541     Net profit   9,247     9,823     576  
      Adjustments to reconcile to cash generated from operating income before changes in working capital:                  
5,092     - amortization and depreciation and other non-monetary items   6,518     5,753     (765 )
(793 )   - net gains on disposal of assets   (220 )   (59 )   161  
5,740     - dividends, interest, taxes and other changes   8,471     10,435     1,964  
17,580     Cash generated from operating profit before changes in working capital   24,016     25,952     1,936  
                         
(909 )   Changes in working capital related to operations   (2,422 )   (1,024 )   1,398  
(4,171 )   Dividends received, taxes paid, interest (paid) received   (6,658 )   (7,927 )   (1,269 )
12,500     Net cash provided by operating activities   14,936     17,001     2,065  
                         
(7,499 )   Capital expenditure   (7,414 )   (7,833 )   (419 )
(316 )   Investments   (127 )   (95 )   32  
1,547     Disposals   542     328     (214 )
97     Other cash flow related to capital expenditure, investments and disposals   293     361     68  
6,329     Free cash flow   8,230     9,762     1,532  
                         
211     Borrowings (repayment) of debt related to financing activities   (109 )   216     325  
(3,743 )   Changes in short and long-term financial debt   (540 )   (682 )   (142 )
(3,175 )   Dividends paid and changes in minority interests and reserves   (7,284 )   (6,443 )   841  
(55 )   Effect of changes in consolidation and exchange differences   33     (201 )   (234 )
(433 )   NET CASH FLOW FOR THE PERIOD   330     2,652     2,322  

     
 
 

 

2004   (million euro)   2005   2006   Change

     
 
 
      Change in net borrowings                  
6,329     Free cash flow   8,230     9,762     1,532  
      Net borrowings of acquired companies   (19 )         19  
190     Net borrowings of divested companies   21     1     (20 )
(64 )   Exchange differences on net borrowings and other changes   (980 )   388     1,368  
(3,175 )   Dividends paid and changes in minority interests and reserves   (7,284 )   (6,443 )   841  
3,280     CHANGE IN NET BORROWINGS   (32 )   3,708     3,740  

     
 
 
     
(a)   For a reconciliation to the statutory Statement of Cash Flows see paragraph “Reconciliation of Summarized Group Balance Sheet and Statement of Cash Flows to statutory schemes” pages 79 and 80.

 

Cash generated by operating activities came in at euro 17,001 million allowing to cover: (i) financial requirements for capital expenditure and investments for euro 7,928 million; (ii) dividend payments amounting to euro 4,832 million, of which euro 2,400 million pertained to the payment of the balance of the dividend for fiscal year 2005 and euro 2,210 million pertained to the payment of an interim dividend for fiscal year 2006 by the parent company Eni SpA. Snam Rete Gas and Saipem also distributed dividends amounting to euro 207 million and (iii) the repurchase of own shares for euro 1,241 million by Eni SpA and for euro 477 million by Snam Rete Gas SpA and Saipem SpA; and along with   cash from divestments (euro 329 million), including net borrowings transferred of euro 1 million (approximately euro 650 million) and currency translation effects to reduce net borrowings by euro 3,710 million.
From January 1, to December 31, 2006 a total of 53.13 million Eni shares were purchased by the company for a total cost of euro 1,241 million (representing an average cost of euro 23.35 per share). Since the inception of the share buy-back program on September 1, 2000 Eni has repurchased 335 million shares, equal to 8.36% of its share capital, at a total cost of euro 5,512 million (representing an average cost of euro 16.45 per share).

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Capital expenditure

 

2004   (million euro)   2005   2006   Change   % Ch.

     
 
 
 
4,853     Exploration & Production   4,965     5,203     238     4.8  
1,451     Gas & Power   1,152     1,174     22     1.9  
693     Refining & Marketing   656     645     (11 )   (1.7 )
148     Petrochemical   112     99     (13 )   (11.6 )
186     Engineering & Construction   349     591     242     69.3  
49     Other activities   48     72     24     50.0  
119     Corporate and financial companies   132     88     (44 )   (33.3 )
      Unrealized profit in inventory         (39 )   (39 )   ..  
7,499         7,414     7,833     419     5.7  


     

 

 

 

 

Capital expenditure amounted to euro 7,833 million, of which 89.7% related to the Exploration & Production, Gas & Power and Refining & Marketing divisions.
Capital expenditure was primarily related to:
  • the development of oil and gas reserves (euro 3,629 million) in particular in Kazakhstan, Angola, Egypt and Italy and exploration projects (euro 1,348 million) particularly in Angola, Egypt, Norway, Nigeria, the Gulf of Mexico and Italy, including also the acquisition of 152,000 square kilometers of new acreage (99% operated by Eni);
  • the upgrading and maintenance of Eni’s natural gas transport and distribution networks in Italy (euro 785 million);
  • ongoing construction of combined cycle power plants (euro 229 million);
  • projects aimed at improving flexibility and yields of refineries (euro 376 million), including the start-up of construction of a new hydrocracking unit at the Sannazzaro refinery, and upgrading the refined product distribution network in Italy and in the rest of Europe (euro 223 million);
  • the construction of a new FPSO unit and upgrading of the fleet and logistic centers in the Engineering & Construction division (euro 591 million);
 
  • actions for environmental protection and for complying with safety and environmental regulations in the Petrochemical division (euro 99 million).

Dividends paid and changes in minority interests and reserves (euro 6,443 million) related mainly to dividend distribution for fiscal year 2005 of euro 2,400 million and the payment of an interim dividend of euro 2,210 million carried out by Eni SpA, the payment of dividends by Snam Rete Gas SpA (euro 161 million), Saipem SpA (euro 46 million) and other consolidated subsidiaries (euro 14 million) and the repurchase of own shares.

From January 1 to June 30, 2006, a total of 53.13 million own shares were purchased at a cost of euro 1,241 million (representing an average cost of euro 23.35 per share). From the beginning of the share buy-back plan (September 1, 2000), Eni purchased 335 million of its own shares, equal to 8.36% of its share capital, for a total expense of euro 5,512 million (representing an average cost of euro 16.45 per share).

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Reconciliation of summarized Group balance sheet and statement of cash flows to statutory schemes

Summarized Group Balance Sheet

(million euro)   December 31, 2005   December 31, 2006
   
 
Items of Summarized Group Balance Sheet
(where not expressly indicated, the item derives directly from the statutory scheme)
  Notes to the Consolidated
Financial Statements
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
   
 
 
 
 
Fixed assets                            
Property, plant and equipment, net             45,013           44,312  
Other assets                         629  
Compulsory stock             2,194           1,827  
Intangible assets, net             3,194           3,753  
Investments accounted for with the equity method and other investments             4,311           4,246  
Accounts receivable financing and securities related to operations   (see note 12 "Other financial assets" and note 3 "Trade and other receivables")         775           557  
Net accounts payable in relation to capital expenditure, made up of:             (1,196 )         (1,090 )
- accounts receivable related to capital expenditure/divestments   (see note 3 "Trade and other receivables")   60           100        
- accounts receivable related to capital expenditure/divestments   (see note 14 "Other non-current assets")   39           2        
- accounts payable related to capital expenditure   (see note 16 "Trade and other payables")   (698 )         (1,166 )      
- accounts payable related to capital expenditure   (see note 23 "Other non-current liabilities")   (597 )         (26 )      
Total fixed assets             54,291           54,234  
Working capital, net                            
Inventories             3,563           4,752  
Trade accounts receivable   (see note 3 "Trade and other receivables")         14,101           15,230  
Trade accounts payable   (see note 16 "Trade and other payables")         (8,170 )         (10,528 )
Taxes payable and reserve for net deferred income tax liabilities, made up of:             (4,857 )         (5,396 )
- income tax payables       (3,430 )         (2,830 )      
- deferred tax liabilities       (4,890 )         (5,852 )      
- income tax receivables       697           658        
- deferred tax assets       1,861           1,725        
- other tax receivables   (see note 14 "Other non-current assets")   905           903        
Reserve for contingencies             (7,679 )         (8,614 )
Other operating assets (liabilities), made up of:             (526 )         (641 )
- securities related to operations   (see note 2 " Other financial assets for trading or available for sale")   465           420        
- accounts receivable financing related to operations   (see note 3 "Trade and other receivables")   480           242        
- other receivables   (see note 3 "Trade and other receivables")   3,249           3,080        
- other (current) assets       369           855        
- other receivables and other assets   (see note 14 "Other non-current assets")   51           89        
- advances, other payables   (see note 16 "Trade and other payables")   (4,227 )         (4,301 )      
- other (current) liabilities       (613 )         (634 )      
- other payables and other liabilities   (see note 23 "Other non-current liabilities")   (300 )         (392 )      
Total working capital, net             (3,568 )         (5,197 )
Employee termination indemnities and other benefits             (1,031 )         (1,071 )
Capital employed, net             49,692           47,966  
   
 
 
 
 

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continued Summarized Group Balance Sheet

(million euro)   December 31, 2005   December 31, 2006
   
 
Items of Summarized Group Balance Sheet
(where not expressly indicated, the item derives directly from the statutory scheme)
  Notes to the Consolidated
Financial Statements
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
   
 
 
 
 
Capital employed, net             49,692           47,966  
Shareholders’ equity including minority interests             39,217           41,199  
Net borrowings                            
Debts and bonds, made up of:             12,998           11,699  
- long-term debt       7,653           7,409        
- current portion of long-term debt       733           890        
- current financial liabilities       4,612           3,400        
Less:                            
Cash and cash equivalents             (1,333 )         (3,985 )
Securities not related to operations, made up of:             (931 )         (552 )
- other financial assets for trading or available for sale held for non-operating purposes   (see note 2 "Other financial assets for trading or available for sale")   (903 )         (552 )      
- other financial assets for non-operating purposes   (see note 12 "Other financial assets")   (28 )                  
Non-operating financing receivables, made up of:             (259 )         (395 )
- trade receivables for non-operating purposes   (see note 3 "Trade and other receivables")   (12 )         (143 )      
- financial assets made for non-operating purposes   (see note 12 "Other financial assets")   (247 )         (252 )      
Total net borrowings (a)             10,475           6,767  
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY             49,692           47,966  
   
 
 
 
 
(a)   For details on net borrowings see also note n. 19.

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Summarized Group Cash Flow Statement

(million euro)   2005   2006
   
 
Items of Summarized Cash Flow Statement
and confluence/reclassification of items in the statutory scheme
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
  Partial amounts
from statutory
scheme
  Amounts
of the summarized Group scheme
   
 
 
 
Net profit         9,247           9,823  
Adjustments to reconcile to cash generated from operating income before changes in working capital:                        
- amortization and depreciation and other non monetary items         6,518           5,753  
  . amortization and depreciation   5,509           6,153        
  . writedowns (revaluations) net   (288 )         (386 )      
  . net change in the reserve for contingencies   1,279           (86 )      
  . net change in the reserve for employee benefit   18           72        
- gain on disposal of assets         (220 )         (59 )
- dividends, interest, extraordinary income (expense)         8,471           10,435  
  . dividend income   (33 )         (98 )      
  . interest income   (214 )         (387 )      
  . interest expense   654           346        
  . exchange differences   (64 )         6        
  . current and deferred income taxes   8,128           10,568        
Cash generated from operating income before changes in working capital         24,016           25,952  
Changes in working capital related to operations:         (2,422 )         (1,024 )
- inventories   (1,402 )         (953 )      
- accounts receivable   (4,413 )         (1,952 )      
- other asstes   351           (315 )      
- trade and other accounts payable   3,030           2,146        
- other liabilities   12           50        
Dividends received, taxes paid, interest (paid) received:         (6,658 )         (7,927 )
- dividends received, taxes paid, interest (paid) received   366           848        
- interest received   214           395        
- interest paid   (619 )         (294 )      
- income taxes paid   (6,619 )         (8,876 )      
Net cash provided by operating activities         14,936           17,001  
Capital expenditure:         (7,414 )         (7,833 )
- intangible assets   (6,558 )         (6,138 )      
- intangible assets   (856 )         (1,695 )      
Investments:         (127 )         (95 )
- consolidated subsidiaries and businesses   (73 )         (46 )      
- investments   (54 )         (42 )      
- acquisition of additional interests in subsidiaries               (7 )      
Disposals:         542           328  
- tangible assets   99           237        
- intangible assets   13           12        
- consolidated subsidiaries and businesses   252           8        
- investments   178           36        
- sale of interests in consolidated subsidiaries               35        
Other cash flow related to capital expenditure, investments and disposals:         293           361  
- securities   (464 )         (49 )      
- financing receivables   (683 )         (516 )      
- change in accounts payable and receivable in relation to investment and capitalized depreciation   149           (26 )      
- reclassification: purchase of securities and financing receivables non related to operations   231           178        
- sale of securities   369           382        
- sale of financing receivables   804           794        
- change in accounts receivable in relation to disposals   9           (8 )      
- reclassification: sale of securities and financing receivables non related to operations   (122 )         (394 )      
Free cash flow         8,230           9,762  
   
 
 
 

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continued Summarized Group Cash Flow Statement

 

(million euro)   2005   2006
   
 
Items of Summarized Cash Flow Statement
and confluence/reclassification of items in the statutory scheme
  Partial amount
from statutory
scheme
  Amounts
of the summarized Group scheme
  Partial amount
from statutory
scheme
  Amounts
of the summarized Group scheme
   
 
 
 
Free cash flow         8,230           9,762  
Borrowings (repayment) of debt related to financing activities:         (109 )         216  
- reclassification: purchase of securities and financing receivables non-related to operations   (231 )         (178 )      
- reclassification: sale of securities and financing receivables non-related to operations   122           394        
Changes in short and long-term financial debt:         (540 )         (682 )
- proceeds from long-term debt   2,755           2,888        
- payments of long-term debt   (2,978 )         (2,621 )      
- reduction of short-term debt   (317 )         (949 )      
Dividends paid and changes in minority interests and reserves:         (7,284 )         (6,443 )
- capital contributions/payments by/to minority shareholders   24           22        
- sale (acquisition) of additional interests in subsidiaries   (33 )         (477 )      
- dividends to shareholders   (6,288 )         (4,832 )      
- shares repurchased, net   (987 )         (1,156 )      
Effect of changes in consolidation and exchange differences:         33           (201 )
- effect of changes in consolidation   (38 )         (4 )      
- effect of exchange differences   71           (197 )      
Net cash flow for the period         330           2,652  
   
 
 
 

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Reconciliation of net profit and shareholders’ equity of the parent company Eni SpA to consolidated net profit and shareholders’ equity

    Net profit   Shareholders’ equity
   
 
(euro million)   2005   2006   Dec. 31, 2005   Dec. 31, 2006
   
 
 
 
As recorded in Eni SpA's Financial Statements   6,042     5,821     26,872     26,935  
Difference between the equity value of individual accounts of consolidated subsidiaries with respect to the corresponding book value in consolidated accounts   2,718     3,837     13,701     16,153  
Consolidation adjustments:                        
- difference between purchase cost and underlying book value of net equity   (44 )   (52 )   1,902     1,138  
- elimination of tax adjustments and compliance with group accounting policies   863     612     (1,528 )   (1,451 )
- elimination of unrealized intercompany profits   (40 )   (207 )   (2,677 )   (2,878 )
- deferred taxation   (313 )   (195 )   849     1,244  
- other adjustments   21     7     98     58  
    9,247     9,823     39,217     41,199  
Minority interest   (459 )   (606 )   (2,349 )   (2,170 )
As recorded in Consolidated Financial Statements   8,788     9,217     36,868     39,029  
   
 
 
 

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Other Information

 

 

Court inquiries
The Milan Public Prosecutor is inquiring into contracts awarded by Eni’s subsidiary EniPower and on supplies from other companies to EniPower. The media has widely covered these inquiries. It emerged that illicit payments were made by EniPower suppliers to a manager of EniPower who was immediately dismissed. The Court presented EniPower (commissioning entity) and Snamprogetti (contractor of engineering and procurement services) with notices of process in accordance with existing laws regulating administrative responsibility of companies (Legislative Decree No. 231/2001). In its meeting of August 10, 2004, Eni’s Board of Directors examined the above mentioned situation and Eni’s CEO approved the creation of a task force in charge of verifying the compliance with Group procedures regarding the terms and conditions for the signing of supply contracts by EniPower and Snamprogetti and the subsequent execution of works. The Board also advised divisions and departments of Eni to fully cooperate in every respect with the Court. From the inquiries performed, no default in the organization emerged, nor deficiencies in internal control systems. External experts have performed inquiries with regard to certain specific aspects. In accordance with its transparency and firmness guidelines, Eni will take the necessary steps in acting as plaintiff in the expected legal action in order to recover any damage that could have been caused to Eni by the illicit behavior of its suppliers and of their and Eni employees. In the meantime, preliminary investigations have found that both EniPower and Snamprogetti are not to be considered defendants in accordance with existing
  laws regulating administrative responsibility of companies (Legislative Decree No. 231/2001).

An investigation is pending regarding two former Eni managers who were allegedly bribed by third parties in order to favor the closing of certain transactions with two oil product trading companies. Within such investigation, on March 10, 2005, the public prosecutor of Rome notified Eni two judicial measures for the seizure of documentation concerning Eni’s transactions with said companies. Eni is acting as plaintiff in this proceeding.


TSKJ Consortium - Investigations
of SEC and other Authorities

In June 2004 the U.S. Securities and Exchange Commission (SEC) notified a request of collaboration on a voluntary basis to Eni, which Eni promptly carried out, in order to obtain information regarding the TSKJ consortium in relation to the construction of natural gas liquefaction facilities at Bonny Island in Nigeria. The TSKJ consortium is formed by Snamprogetti (Eni 43.54%) with a 25% interest and, for the remaining part, by subsidiaries of Halliburton/KBR, Technip and JGC. The SEC investigations concern alleged improper payments made by the TSKJ consortium to certain public officials. Eni’s subsidiary Snamprogetti is conducting its own investigations on those alleged improper payments. Other authorities are currently investigating this matter. Eni and its subsidiary Snamprogetti are currently providing documentation and information to the SEC and other authorities, providing the necessary support.

 

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Subsequent events
Main subsequent events are reported in the Operating Review above.

Business trends
The outlook for Eni in 2007 remains positive, with key business trends for the year as follows:
  • production of liquids and natural gas is forecast to remain on the same level as 2006 (1.77 mmboe/d). Mature field decline in Italy and in the North Sea is expected to be offset by a growth in Libya, due to the build-up of the Western Libyan Gas Project;
  • sales volumes of natural gas are forecast to increase from 2006 levels (97.48 bcm), increases are expected in the Iberian Peninsula, German/Austrian and French markets;
  • sold production of electricity is expected to increase from 2006 levels (24.82 TWh) due to the ramp-up of production capacity in Brindisi and the planned start-ups of new capacity at the Ferrara power plant;
 
  • refining throughputs on Eni’s account are forecast to decline slightly from 2006 (38.04 mmtonnes), due to the termination of the contract for processing certain volumes of crude at the Priolo refinery’s facilities owned by a third party, to be offset by higher throughputs expected at the Gela, Livorno and Sannazzaro refineries;
  • retail sales of refined products are expected to slightly increase in Italy due to planned marketing initiatives, and in the rest of Europe due to new acquisitions of service stations in target markets.

In 2007, management expects to increase capital expenditure from the 2006 level (euro 7.83 billion).
Increases will be apportioned to the development of oil and natural gas reserves, upgrading of refineries and the retail network and upgrading of natural gas import and transport infrastructure.

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Corporate Governance

 

 

Code of Conduct
The Board of Directors of Eni has deemed it appropriate to provide a clear definition of the value system that Eni recognizes, accepts and upholds and the responsibilities that Eni assumes within its Group and externally in order to ensure that all Group activities are conducted in compliance with laws, in a context of fair competition, with honesty, integrity, correctness and in good faith, respecting the legitimate interests of shareholders, employees, suppliers, customers, commercial and financial partners and the communities where Eni operates. All those working for Eni, without exception or distinction, are committed to observing these principles within their function and responsibility and to ensure that others observe them.
The belief of working for the advantage of Eni is not a justification for behaviours contrary to such principles.
These values are stated in a Code of Conduct whose observance by employees is evaluated by the Board of Directors, based on the annual report of the Guarantor for the Code of Conduct.
The Code of Conduct is published on Eni’s website www.eni.it.

Self-discipline Code
In its meeting of January 20, 2000, Eni’s Board of Directors resolved to adopt the first “Self-discipline Code of Listed Companies” published by Borsa Italiana SpA and underscored how Eni’s organizational model is essentially in line with the principles expounded in the Code, as well as with related recommendations issued by Consob.

In its meeting of December 13, 2006, the Board of Directors decided to conform to the Code of Conduct
  for listed companies, as issued by Borsa Italiana in March 2006 (“Borsa Italiana Code”) by adopting an Eni Code (the “Code”). The Eni Code is based on the Borsa Italiana Code and adapts certain recommendations of the Borsa Italiana Code to the specific circumstances of Eni, clarifying certain others which resulted in a further improvement of Eni’s corporate governance. The aim of the Code is to clearly and fully disclose Eni’s corporate governance system.

The Code takes into consideration the fact that Eni is a parent company, is not controlled by any other company and – in the light of the recent provisions of the companies law reform – is not subject to direction and co-ordination by any Italian or foreign entity (company or body); hence, all the principles expounded in the Borsa Italiana Code not consistent with this status have been adjusted to avoid misunderstanding among Eni’s shareholders and stakeholders.
Similarly, the By-Laws currently in force foresee a traditional administration and control model (removing the possibility to adopt a one-tier or a two-tier model of management and control system as foreseen in the Borsa Italiana Code), the separation of the positions held by the Chairman and the CEO (making the appointment of a lead independent director unnecessary), and specific rules on the appointment and composition of the Board of Directors and of the Board of Statutory Auditors.

The Eni Code directly makes specific choices where the Borsa Italiana Code leaves this option to listed companies, making further amendments unnecessary and guaranteeing more transparency and

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understanding (i.e., the choice not to re-allocate or modify the Board’s internal committees functions, the choice to entrust internal control responsibilities to only one managerial position, to require the internal control manager to refer to the CEO and the choice not to entrust internal auditing activities to third parties).

Certain principles regarding Shareholders’ Meeting’s duties proposed by the Borsa Italiana Code were merely indicated or suggested by the Board of Directors that cannot inpose decisions to the Shareholders' Meeting. All this notwithstanding, the Board is committed to ensure that the Shareholders and the Shareholders’ Meeting focus a fair deal of attention on such issues, or otherwise promote integrations to Eni By-laws.
Certain generic recommendations of the Borsa Italiana Code have been specified in the Eni Code, in particular criteria regarding the independence of directors by clearly wording the definition of “supplementary remuneration”, which jeopardizes the independence requirement, and the meaning of “close relatives”.

The Eni Code establishes certain principles that enhance the level of governance suggested by the Borsa Italiana Code; in particular:
  • the directors have adopted a guideline which takes into consideration the interests of all stakeholders when pursuing the objective of creating value for the Company’s shareholders;
  • the minimum frequency of the information to be supplied to the Board of Directors by the directors holding proxies has been reduced to two months as compared with the minimum three-month period envisaged by the Borsa Italiana Code;
  • the Board’s self-evaluation can be performed with the support of a specialized external consultant, to ensure its objectiveness;
  • directors and auditors shall hold their positions only as long as they deem to be able to devote the necessary time to diligently perform their duties;
    the number of members of Board committees shall be lower than the majority of Board members in order not to interfere with the Board’s decision-making process;
  • the Internal Control Committee’s opinion on corporate rules has been introduced, ensuring that all transactions carried out with related parties and transactions in which a director has an interest, are performed in a transparent way and according to the criteria of substantial and procedural fairness;
  • the proposal of appointment of the manager delegated to internal control to the Board of Directors is drafted by the CEO, in agreement with the Chairman;
 
  • at least two members of the Internal Control Committee must have adequate experience in accounting and finance (the Borsa Italiana Code foresees only one member with these skills).

The Board of Statutory Auditors was invited to expressly agree to the provisions of the Borsa Italiana Code on the Board of Statutory Auditors, and promptly adhered during their December 13, 2006 meeting.

In its meeting of December 13, 2006, the Board of Directors approved several rules regarding the implementation and specifying the provisions of the Code; in particular:

  • the tasks of the Board of Directors have been redefined: the Board maintains an absolute central role in Eni’s corporate governance system, with wide responsibilities that cover also Eni and its subsidiaries’ organization;
  • the most important transactions of Eni and its subsidiaries, that require the approval of the Board of Directors, have been defined;
  • the Board of Directors has a central role in defining sustainability policies and approving the sustainability report submitted also to the Shareholders’ Meeting;
  • the subsidiaries with strategic relevance have been identified;
  • the Board of Directors has expressed its position on the admissible maximum number of positions in other companies that can be held by Eni’s directors to ensure a sufficient amount of time for the effective performance of their duties;
  • the principle of the respect of managerial autonomy of subsidiaries that are also listed on a regulated market (as Saipem and Snam Rete Gas) has been expressly stated as well as Eni’s commitment to observing such principles as defined in the Borsa Italiana Code regarding persons holding significant positions in the share capital of listed companies.

In its meeting of March 16, 2007, the Board of Directors implementing the prescriptions of the Code and with the positive opinion of the Internal Control Committee, entrusted the Internal Audit Manager as manager delegated for the Internal control.
In its meeting of March 29, 2007, the Board of Directors approved changes in the regulations regarding the functioning and the tasks of the Internal Control Committee and the Compensation Committee, to align them to the prescriptions of the Eni Code.

* * *

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Eni’s corporate governance model, therefore, complies with the provisions of the Borsa Italiana Code and foresees certain provisions intended to improve the level of corporate governance. In relation to the compliance with the recommendations of the Code, the only items still to be implemented, but currently under realization, deal essentially with:
  • the editing of a procedure for transactions with related parties, waiting for the issuing of general principles which Article 239-bis of the Civil Code assigns to Consob. Pending the publication of such rules by Consob, Eni’s internal rules provide that transactions with related parties are submitted to the Board of Directors, even when amounting to less than the materiality threshold set for the transactions to be approved by the Board;
  • the alignment of the number of members of Board Committees which, as foreseen by the Eni Code, should not represent the majority of Board’s members.


Eni’s Code of Conduct has been published on Eni’s website. The “Comment” present in the Borsa Italiana Code has not been included, in order to not lengthen the document, however Eni took it into account in the implementation of principles and criteria.

* * *

In accordance with the requirements and indications of Borsa Italiana SpA, in particular, the “Guidelines for the preparation of the yearly report on corporate governance” of February 12, 2003, follows information on Eni’s corporate governance system. The “Guide to the preparation of the report on corporate governance” published by Assonime and Emittenti Titoli SpA in March 2004 has also been taken into account in preparing this report.

Eni’s organizational structure
Eni’s organizational structure follows the traditional model of companies in which management is entrusted exclusively to the Board of Directors, which is the central element of Eni’s corporate governance system. Monitoring functions are entrusted to the Board of Statutory Auditors and accounting control is entrusted to external auditors appointed by the Shareholders’ Meeting.
According to Article 25 of Eni’s By-laws, the Chairman and the CEO represent the company. The Board of Directors established committees with consulting and proposing functions.

  The Board of Directors
Competencies
On June 1, 2005, the Board of Directors appointed Mr. Paolo Scaroni as Chief Executive Officer and delegated all necessary powers for the administration of the Company to him, with the exception of those powers that cannot be delegated in accordance with current legislation (Article 2381 of the Italian Civil Code) and those retained by the Board of Directors (as amended by the Board of Directors in its meeting of October 11, 2005).
As mentioned above, in its meeting of December 13, 2006, the Board of Directors modified these resolutions in order to update their contents to the Code’s prescriptions, implement a more effective coordination with the By-laws and entrust the Board of Directors with a central role in the Group’s sustainability policies.
The Board, in accordance to these rules, retained the following powers, in addition to those that cannot be delegated under applicable laws:
1. Establishes the Company and Group Corporate Governance system and rules. In particular, after consulting the Internal Control Committee, the Board approves the rules that ensure the substantial and procedural transparency and correctness of the transactions carried out with related parties and those in which a director holds an interest, on his behalf or on behalf of third parties. The Board adopts a procedure for the management and disclosure to third parties of documents and information concerning the Company, having special regard to price sensitive information.
2. Establishes among its members one or more committees with proposing and consulting functions, appoints their members, establishes their responsibilities, determines their compensation and approves their regulations.
3. Appoints and revokes the powers of the Chief Executive Officer and the Chairman; establishes the terms, limits and operating methods of the exercise of such powers and determines the compensation related to the powers, on the basis of proposals from the Compensation Committee and after consulting the Board of Statutory Auditors. The Board may issue instructions to the Chief Executive Officer and the Chairman and reserve to itself any operations that pertain to its powers.
4. Establishes the guidelines of the organizational, administrative and accounting structure of the Company, of the most important controlled subsidiaries and of the Group; evaluates the adequacy of the organizational, administrative and accounting structure set up by the Chief Executive Officer in particular with regard to the management of conflicts of interest.

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5. Establishes, in particular, based on the recommendations of the Internal Control Committee, the guidelines of the internal control system, in order to ensure the identification, measurement, management and monitoring of the main risks faced by the Company and its subsidiaries. Evaluates the adequacy, effectiveness and effective functioning of the internal control system managed by the Chief Executive Officer on an annual basis.
6. Establishes, based on the recommendation of the Chief Executive Officer, Company and Group strategies and objectives, including sustainability policies. Examines and approves the Company’s and Group’s strategic, operational and financial plans and the strategic agreements to be signed by the Company.
7. Examines and approves annual budgets for Eni’s Divisions and the Company, as well as the Group’s consolidated budget.
8. Evaluates and approves interim quarterly and half-yearly reports, as per current regulations. Evaluates and approves the sustainability report, submitted also to the Shareholders’ Meeting.
9. Receives from Board members with powers, at every Board meeting or at least every two months, reports informing the Board of activities carried out in exercising the powers attributed as well as updates on activities carried out by the Group and on atypical or unusual transactions or transactions with related parties that were not previously submitted to the evaluation and approval of the Board.
10. Receives half-year updates on the Board Committees’ activities.
11. Evaluates the general performance of the company and the Group, on the basis of information received from Board members with powers, with particular attention to situations of conflicts of interest and compares results achieved – as contained in the annual report and interim financial statements, as per current regulations – with the budget.
12. Evaluates and approves any transaction executed by the Company and its subsidiaries that have a significant economic, patrimonial and/or financial impact, with particular attention to situations in which Board members hold an interest on their own behalf or on behalf of third parties, and to related parties transactions. The Board ensures the principle of operational autonomy with specific regard to the listed companies of the Eni Group.
  Transactions with a significant economic, patrimonial and/or financial impact include the following:
a) acquisition and sale of shares, companies, branches of companies, and properties, capital contributions in kind, mergers and de-mergers exceeding euro 50 million, notwithstanding Article 23.2 of the By-laws;
b) investments in fixed assets exceeding euro 100 million, or less if of particular strategic importance or particularly risky;
c) any exploration initiatives and portfolio operations in the E&P sector in new areas;
d) sale and purchase of goods and services other than investments, for an amount exceeding euro 1 billion or a duration exceeding twenty years;
e) financing to non-controlled companies: i) for amounts exceeding euro 50 million or, ii) in any case, if the amount is not proportionate to the interest held;
f) issuing by the Company of personal and real guarantees to non-controlled companies: i) for amounts exceeding euro 200 million, if in the interest of the Company or of Eni subsidiaries, or ii) in any case, if the guarantees are issued in the interest of non-controlled companies and the amount is not proportionate to the interest held. In order to issue the guarantees indicated in section i) of letter f), if the amount is between euro 100 million and euro 200 million, the Board confers powers to the Chief Executive Officer and the Chairman, to be exercised jointly in case of urgency.
13. Appoints and revokes, on recommendation of the Chief Executive Officer and in agreement with the Chairman, the General Managers of Divisions and attributes powers to them.
14. Appoints and revokes, on recommendation of the Chief Executive Officer and in agreement with the Chairman, and with the approval of the Board of Statutory Auditors, the Manager charged with preparing the Company's financial reports as per Legislative Decree No. 58/1998 delegating to him adequate powers and resources.
15. Appoints and revokes, on recommendation of the Chief Executive Officer and in agreement with the Chairman, after consulting the Internal Control Committee, the person in charge of internal control and determines his/her compensation in line with the Company’s remuneration policies.
16. Ensures a person is identified as responsible for handling the relationships with the Shareholders.
17. Establishes, on the basis of the proposals received from the Compensation Committee, the criteria for top management compensation and implements the stock incentive plans approved by the Shareholders’ Meeting.

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18. Examines and decides on proposals submitted by the Chief Executive Officer with respect to voting powers and to the appointment of members of the management and control bodies of the most important controlled subsidiaries. With specific regard to the shareholders’ meetings of listed companies of the Eni Group, the Board ensures the observance of the Corporate Governance Rules regarding the shareholders’ meetings.
19. Prepares the proposals to be submitted to the Shareholders' Meetings.
20. Examines and resolves on other matters that the Chief Executive Officer deems appropriate to submit to the Board because of their importance and sensitivity.
Pursuant to Article 23.2 of the By-laws, the Board resolves on: mergers by incorporation and proportional demergers of at least 90% directly owned subsidiaries; establishment and winding up of branches; amendments to the By-laws in order to comply with applicable legislation.
On June 1, 2005, the Board of Directors entrusted the Chairman with powers to conduct strategic international relations, pursuant to Article 23.1 of Eni’s By-laws.
In accordance with Article 27 of Eni’s By-laws, the Chairman chairs Shareholders’ Meetings and oversees the implementation of decisions made by it.

Appointment
In accordance with Article 17 of Eni’s By-laws, the Board of Directors is made up of three to nine members. The Shareholders’ Meeting determines the number within said limits. As per Article 6, paragraph 2, letter d) of Eni’s By-laws the Minister for Economy and Finance, in agreement with the Minister of Economic Development, may appoint one member of the Board without voting rights in addition to those appointed by the Shareholders’ Meeting.
The Minister for Economy and Finance chose not to appoint such member.
The Board of Directors presently in office is made up of nine members appointed by the Shareholders’ Meeting of May 27, 2005, for a three-year term; their mandate expires with the Meeting convened to approve financial statements for fiscal year 2007.
The appointment of the Board of Directors calls for a list vote.
Shareholders representing at least 1% of voting shares, alone or together with other shareholders, and the Board of Directors have the right to present lists for the appointment of directors. Each shareholder can present or participate in presenting only one list.
  Companies controlling a shareholder and companies controlled by the same entity are forbidden from presenting or otherwise concurring to the presentation of additional lists.
Lists are to be filed at Eni’s headquarters at least ten days before the date set for the Shareholders’ Meeting on first call (20 days in case of the Board of Directors presenting a list) and published in national newspapers. Lists must include statements in which each candidate attests the possession of the honorability and independence requirements as provided for by the applicable legislation and Eni’s By-laws. A professional curriculum of each candidate is recommended.

Composition
The current Board of Directors is formed by the Chairman, Roberto Poli, the CEO, Paolo Scaroni, and directors, Alberto Clô, Renzo Costi, Dario Fruscio, Marco Pinto, Marco Reboa, Mario Resca, and Pierluigi Scibetta.
Roberto Poli, Paolo Scaroni, Dario Fruscio, Marco Pinto, Mario Resca and Pierluigi Scibetta were candidates included in the list of the Ministry of Economy and Finance; Alberto Clô, Renzo Costi and Marco Reboa were in the list presented by institutional investors coordinated by Fineco Asset Management SpA.
Since June 1, 2006, the Secretary of the Board of Directors is Roberto Ulissi, the Group’s senior vice president for Corporate Affairs and Governance.

Positions held in other Boards
Based on information received, follows information on positions held in other Boards of Directors or Boards of Statutory Auditors of companies listed in regulated markets also outside Italy, financial, banking or insurance or large companies by members of Eni’s Board of Directors. The professional curriculum of Directors is available on Eni’s website.

ROBERTO POLI
Board member of Mondadori SpA, Fininvest SpA, Merloni Termosanitari SpA e G.D. SpA.

PAOLO SCARONI
Board member of Il Sole 24 Ore and Il Teatro alla Scala. Member of the Supervisory Board of ABN AMRO Bank, Board member of the Columbia University’s Business School and Veolia Enviroment (Paris).

ALBERTO CLÔ
Independent Board member of ASM Brescia SpA, Società Autostrade SpA, Italcementi SpA and De Longhi SpA.

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RENZO COSTI
Board member of Editrice Il Mulino SpA.

DARIO FRUSCIO
Chairman of Italia Turismo SpA.

MARCO REBOA
Board member of Seat PG SpA, Interpump Group SpA, IMMSI SpA and, among others Intesa Private Banking SpA. Chairman of the Board of Statutory Auditors of Luxottica Group SpA.

MARIO RESCA
Chairman of Italia Zuccheri SpA, Board member of Mondadori SpA, Special manager of the Cirio Del Monte Group, under special management.

PIERLUIGI SCIBETTA
Board member of Nucleco SpA, Istituto Superiore per la Previdenza e la Sicurezza del Lavoro (I.S.P.E.S.L.), Gestore del Mercato Elettrico SpA and of Ente per le nuove tecnologie, l'energia e l'ambiente - ENEA.

Board’s opinion on the matter of the admissible number of positions held by directors in other companies
In its meeting of December 13, 2006, the Board of Directors expressed its opinion on the matter of the admissible number of positions held by directors in other companies, as required by Eni’s Self-discipline Code:
  • an executive director should not hold: i) the position of executive director in any other Italian or foreign listed company, or in any finance, banking or insurance company or any company with a net equity exceeding euro 10 billion and ii) the position of non-executive director or statutory auditor (or member of any other advisory committee) in more than three of said companies;
  • a non-executive director, should not hold further positions than the one held in Eni, as: i) executive director in more than one of the companies mentioned above and non-executive director or statutory auditor (or member of any other control body) in more than three of the mentioned companies, or as ii) non-executive director or statutory auditor in more than six of the mentioned companies.

All the positions held in Eni’s subsidiaries are excluded for the purposes described above.
In case a director exceeds said limits in terms of positions held, he should timely inform the Board, who shall judge the situation taking into account the interest of the Company and call upon the interested director to make a decision on the matter.

  On the basis of available information, Eni’s directors comply with these limits on the number of positions held in other companies.

Independence and honorability
Legislative Decree No. 58 of February 24, 1998 (TUF), as amended by Legislative Decree No. 303 of December 29, 2006 states that at least two members in a Board composed by more than seven members must possess the independence requirements provided for Statutory Auditors of listed companies.
Article 17.3 of Eni’s By-laws states that at least three Board members shall have the independence requirement, in case the Board is made up by more than five members. This rule actually increases the number of independent directors in Eni’s Board. Eni’s Code foresees further independence requirements, in line with the ones provided by the Borsa Italiana Code.
On February 22, 2007, Eni’s Board of Directors, in accordance with the provisions of Eni’s By-laws and Code, determined that six out of its nine members are independent, specifically: non-executive Directors Alberto Clô, Renzo Costi, Dario Fruscio, Marco Reboa, Mario Resca and Pierluigi Scibetta.
Renzo Costi was confirmed to be independent notwithstanding his permanence as board member for a period longer than nine years, due to the fact that he has been nominated by minority shareholders (specifically institutional investors) and has demonstrated ethical and professional qualities and independence when expressing his opinion during this period.
The Board of Statutory Auditors verified the proper application of criteria and procedures adopted by the Board to evaluate the independence of its members.
In accordance with the TUF, implemented in Article 17.3 of Eni’s By-laws, the Directors and General Managers of listed companies shall possess the honorability requirements prescribed for statutory auditors.
On February 22, 2007, the Board of Directors verified that all its members possess the honorability requirements.
In accordance with Article 17.3 of Eni’s By-laws, should the independence and honorability requirements be impaired or cease or the minimum number of independent Directors diminish below the threshold set by Eni’s By-laws, the Board declares the termination of office of the member lacking said requirements and provides for his substitution.

Meetings and functioning
In 2006, the Board of Directors met 16 times (21 in 2005) for an average duration of three hours.

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The general public is informed, with advance notice, of: (i) the dates of meetings convened for the approval of annual, semi-annual, preliminary and interim accounts; (ii) the dates of meetings convened to announce the amount of interim dividends and final dividends, and related ex-dividend and payment dates, and (iii) the dates of the general Shareholders’ Meeting approving the annual financial statements.
The financial calendar is available on Eni’s website.
In its meeting of June 1, 2005, the Board of Directors defined the rules for the calling of its meetings; in particular, the Chairman convenes Board meetings, and, in agreement with the CEO, defines agenda items. Notice is sent to the Directors, Statutory Auditors and the Magistrate of the Court of Accounts, by mail, fax, or e-mail within five days of the meeting’s date, at least 24 hours in advance in case of urgency.
Eni’s By-laws allow meetings to be held by video or teleconference.
Board members, Statutory Auditors and the Magistrate of the Court of Accounts receive in advance adequate and thorough information on all issues subject to Board evaluation and resolutions, except when confidentiality is deemed necessary.
During meetings directors can meet managers of Eni and its subsidiaries in order to obtain information on specific matters of the agenda items.
In 2006, on average 85% of Board members participated to Board meetings and 84% of independent non-executive Board members.
In the attached table, the percentage of attendance of each member of the Board to the Board of Directors’ and Board committees’ meetings is presented.
On September 21, 2006, the Board of Directors’ meeting was held on the Sabratha platform, off the Libyan coast, to allow non-executive directors to increase their knowledge on how Eni’s businesses operate.
Until this date, non-executive and independent members have always met in presence of the other members of the Board; Eni’s By-laws allow them to decide whether it is necessary to hold meetings attended exclusively by non-executive and independent members.

Board self evaluation
The Board of Directors performed its first evaluation of size, composition and functioning of the Board itself, in accordance with Eni’s and Borsa Italiana Codes.
In accordance with Eni’s Code, the Board of Directors has received support by a specialized consulting firm, Egon Zehnder, to guarantee the objectiveness of its evaluations.
Egon Zehnder’s work was focused on: a) gaining insight on the level of functioning and efficiency of the Board;
  b) identifying areas of improvement or weakness in the functionality and efficiency of the Board. Consultants performed an in-depth interview of each member and analyzed the quantitative and qualitative aspects of all the information obtained.
The results of the interviews performed by Egon Zehnder were presented to the Board of Directors, being present the Board of Statutory Auditors. In its meeting of February 22, 2007, the Board reviewed the findings of the consultant and judged the size, composition and functioning of the Board and of the committees of the Board to be substantially positive. This conclusion shared by the consultant.
The main qualifying items underlined by the Board of Directors are: the open and direct discussion during the meetings; the respect for the contribution of each member; a constructive approach on part of all Board members to reach consensual solutions; the completeness, transparency and timeliness of information prepared by the CEO for Board meetings, and of explanations provided by the CEO during the meetings in order to allow the Board to perform its role being well informed and aware of the issues on the agenda.
All Directors have agreed on the personal contribution of each member to the optimization of the reviews made by the Board, thus allowing the Board to fully benefit from the different skills and professional backgrounds of each member, resulting in a more informed and consensual influence on the resolutions of the Board.
The Directors also agreed upon holding informal meetings to gain more insight on specific managerial and business matters, in order to better perform assigned duties.

Remuneration
Board members’ emoluments are determined by the Shareholders’ Meeting, while the emoluments of the Chairman and CEO, in relation to the powers attributed to them, are determined by the Board of Directors, based on proposals of the Compensation Committee and after consultation with the Board of Statutory Auditors.
On May 27, 2005 the Shareholders’ Meeting resolved to determine the annual emolument of the Chairman in euro 265,000 and of Board members in euro 115,000. It also resolved a bonus up to a maximum of euro 80,000 for the Chairman and euro 20,000 for each Board member. The amount of the bonus is determined in accordance with the performance of Eni shares in the reference year as compared with the performance of the seven largest international oil companies for market capitalization.

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The share performance takes account of the dividend paid. Said bonus amounts to euro 80,000 or euro 40,000, and euro 20,000 or euro 10,000 for the Chairman and each Board member, respectively, depending on whether the performance of Eni shares is rated first or second, or third or fourth in the reference year, respectively. No bonus is paid in case Eni scores a position lower than the fourth one.
In the meeting of June 21, 2006, the Board verified that Eni rated third in the mentioned positioning in 2005.
In the meeting of July 27, 2006, the Board of Directors, as proposed by the Compensation Committee and advised by the Board of Statutory Auditors, determined an additional element of remuneration for the Board members holding positions in Board’s committees, with the exclusion of the Chairman and CEO. Said fee amounts to euro 30,000, and euro 20,000 for the position of chairman of a committee and of member of a committee, respectively. This amount decreases to euro 27,000 and euro 18,000 in case a member holds positions in more than one committee.
The remuneration of the Chairman is made up of both a fixed emolument and a variable part in relation to the powers delegated to him by the Board.
The remuneration of the CEO, the general managers and other managers with strategic responsibilities1 is made up by a salary, a bonus, and a long term incentive. The CEO also earns a fixed emolument and a variable part in relation to the powers delegated to him by the Board.
The salary of the three General Managers of Eni divisions and of other key managers is defined considering the position held and their specific responsibilities, taking into account the compensation level adopted by domestic and worldwide companies (in oil and gas, industrial and service sectors) and aligning it on a yearly base considering individual performance and career progression.
The variable part of the remuneration is paid yearly, based on the achievement of specific financial, operational and strategic targets and of individual performance goals pertaining to each business or functional unit. The variable part of the Chairman’s and CEO’s remuneration is determined based on the achievement of specific company objectives.
The variable part paid in 2006 was determined based on the achievement of Eni’s target for 2005 as approved by the Board of Directors on proposal of the Compensation Committee and defined consistently
  with the targets of the strategic plan and yearly budget. Said targets include a set level of cash flow from operations (with a 40% weight), profitability (30%) and divisional operating performance (30%). Results achieved have been assessed assuming a constant trading environment and have been verified by the Compensation Committee and approved by the Board of Directors. Based on these results, a variable amount equal to 125% of the target level was determined, within an interval ranging from 85% to 130% of said target level.
In March 2006, the Board of Directors approved a new long-term incentive plan for senior managers of Eni and its subsidiaries (excluding listed subsidiaries), as proposed by the Compensation Committee. This new scheme is intended to motivate more effectively and retain managers, linking incentives to targets and performance achieved in a tighter way than previous incentives schemes. This new incentive scheme applies to the 2006-2008 three year period and is composed of a deferred monetary incentive, linked to the achievement of certain business growth and operating efficiency goals, replacing the previous stock grant plan, and of a stock option incentive focused on the achievement of certain targets of total shareholder return. This stock-based incentive was approved by the General Shareholders’ Meeting of May 25, 2006.
This scheme has a structure that balances the monetary and stock-based components of the remuneration, as well as links economic and operating performance to share performance in the long term. The deferred monetary incentive assigned in 2006 is paid after three years from the assignment depending on the achievement of the annual EBITDA targets preset for the 2006-2008 period. Results in terms of EBITDA are assessed by comparing actual results with set targets under a constant trading environment for each year. Stock options assigned in 2006 can be exercised after three years from the assignment in a percentage depending on the performance of Eni shares measured in terms of Total Shareholder Return2 as compared to that achieved by a panel of major international oil companies over the 2006-2008 three-year period (see below).
At the end of the three year period, the results of the long term incentive plan are analyzed by the Compensation Committee and approved by the Board of Directors.
The CEO, being the General Manager of the company,

 


(1)   These managers together with the CEO and the General Managers are permanent members of Eni’s Management Committee.
(2)   For a definition of TSR see “Glossary”.

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is entitled to take part to both legs of this scheme, adding also a deferred bonus linked to the increase in the Eni share price, to be paid after three years (see the paragraph “Stock options and other share-based compensation”, below).   Follows the breakdown of the 2006 remuneration of the Chairman, the CEO, the divisional General Mangers and other managers with strategic responsibilities taking account of the fixed and variable components paid in the year, and the assigned long term incentive:

 

(%)  

     

 

   Chairman

 

CEO

 

Divisional General Managers

 

Other managers with strategic responsibilities

       
 
 
 
Fixed remuneration   65   32   38   41
Variable remuneration (linked to performance)   35   18  (*) 26   26
Long term incentive (linked to performance) (**)   -   50   36   33
Total   100   100   100   100
       
 
 
 
     
(*)   Determined on the actual period of office from June 1, 2005.
(**)   Evaluation of the deferred bonus (discounted) and the fair value of stock options assigned for target results. For the CEO, the deferred bonus comprises also the deferred bonus linked to the market performance of Eni shares.

 

Eni’s Shareholders’ Meeting of May 25, 2006, determined to extend to all Board Directors and to Statutory Auditors the insurance against professional risks included in agreements for Eni managers. This insurance reflects market terms and standard conditions.

Remuneration earned by members of the Board of Directors, Statutory Auditors, General Managers, and other managers with strategic responsibilities
Pursuant to Article 78 of Consob Decision No. 11971 of May 14, 1999, and to its subsequent modifications, remuneration earned by members of the Board of Directors, Statutory Auditors, General Managers and other managers with strategic responsibilities is reported in the table below. Remuneration earned by managers who held a position in 2006 for a fraction of the year is reported too.
Pursuant to Consob decisions:
  • in the column “Emoluments for service at Eni SpA” are reported fixed fees paid to non-executive and executive directors, fixed fees paid to Directors attending the Committees formed by the Board of Directors, and fees paid to Statutory Auditors. Fixed fees earned by the Chairman and the CEO include also fees earned for the powers delegated to them by the Board;
  • in the column “Non-cash benefits” are reported amounts referring to all fringe benefits, including insurance policies;
 
  • in the column “Bonuses and other incentives” are reported the portion of fees linked to performances which was awarded in the year to both non-executive directors and executive directors, and the portion of salaries linked to performances which was awarded in the year to the CEO, the General Managers of Eni’s divisions and other managers with strategic responsibilities;
  • in the column “Salaries and other elements” are reported base salaries paid to the CEO, the General Managers of Eni’s divisions and other managers with strategic responsibilities, and indemnities paid upon termination of the employment contract. Referring to the Statutory Auditors, fees paid for positions held on the Board of Statutory Auditors in Eni’s subsidiaries are also reported.

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(thousand euro)                                
Name  

Position

 

Term of office

 

Expiry date of the position (1)

 

Emoluments
for service
at Eni SpA

 

Non-cash benefits

 

Bonuses and other incentives (2)

 

Salaries and
other elements

 

Total


 
 
 
 
 
 
 
 
Board of Directors                                      
Roberto Poli   Chairman   01.01-12.31   05.30.08   765   15   415           1,195  
Paolo Scaroni   CEO   01.01-12.31   05.30.08   430   62   834  (3)   1,014     2,340  
Alberto Clô   Director   01.01-12.31   05.30.08   134       10           144  
Renzo Costi   Director   01.01-12.31   05.30.08   130       10           140  
Dario Fruscio   Director   01.01-12.31   05.30.08   124       10           134  
Marco Pinto   Director   01.01-12.31   05.30.08   130       10           140  
Mario Resca   Director   01.01-12.31   05.30.08   128       10           138  
Marco Reboa   Director   01.01-12.31   05.30.08   134       10           144  
Pierluigi Scibetta   Director   01.01-12.31   05.30.08   130       10           140  
Board of Statutory Auditors                                      
Paolo Andrea Colombo   Chairman   01.01-12.31   05.30.08   115             89  (4)   204  
Filippo Duodo   Auditor   01.01-12.31   05.30.08   80             55  (5)   135  
Edoardo Grisolia (6)   Auditor   01.01-12.31   05.30.08   80                   80  
Riccardo Perotta   Auditor   01.01-12.31   05.30.08   80             63  (7)   143  
Giorgio Silva   Auditor   01.01-12.31   05.30.08   80             44  (8)   124  
General Managers                                      
Stefano Cao   Exploration & Production   01.01-12.31               643     966     1,609  
Domenico Dispenza   Gas & Power   01.01-12.31               386     669     1,055  
Angelo Taraborrelli   Refining & Marketing   01.01-12.31               400     645     1,045  
                2,540   77   2,748     3,565     8,910  
Other managers with strategic responsibilities (9)                       1,932     7,846  (10)   9,778  

 
 
 
 
 
 
 
 
     
(1)   Office ends with the Meeting approving financial statements for the year ending December 31, 2007.
(2)   Based on performance achieved in 2005.
(3)   Amount accrued for the duration of office from June 1 to December 31, 2005.
(4)   Includes the compensation obtained as Chairman of the Board of Statutory Auditors of Saipem and EniServizi.
(5)   Includes the compensation obtained as Statutory Auditor in Snamprogetti SpA, Chairman of the Board of Statutory Auditors of CEPAV Uno and CEPAV Due.
(6)   Compensation for the service is paid to the Ministry of Economy and Finance.
(7)   Includes the compensation obtained as Chairman of the Board of Statutory Auditors of Snam Rete Gas and as Statutory Auditor in Enifin SpA.
(8)   Includes the compensation obtained as Statutory Auditor in Snamprogetti SpA and as Chairman of the Board of Statutory Auditors of TSKJ Italia Srl.
(9)   Managers, who during the year with the CEO and the General Managers of Eni divisions, have been members of Eni’s Steering Committee (nine managers).
(10)   Also Includes indemnities paid upon termination of employment contract.

 

Deferred bonus awarded to the CEO, the General Managers and managers with strategic responsibilities
The deferred bonus plan approved for the 2006-2008 three-year period envisages a basic bonus paid after three years according to a variable amount equal to a percentage ranging from 0 to 170% of the amount
  established for the target performance in relation to the performances achieved in a three-year period as approved by the Board of Directors.
The following table sets out the basic bonus awarded in the year 2006 to the CEO and to the General Managers of Eni’s Divisions, and the total amount awarded to other managers with strategic responsibilities.

 

(thousand euro)

Name       Deferred bonus awarded

 
 
Paolo Scaroni   CEO   787
Stefano Cao   General Manager of the E&P Division   468
Domenico Dispenza   General Manager of the G&P Division   328
Angelo Taraborrelli   General Manager of the R&M Division   307
Other managers with strategic responsibilities (1)       1,293

 
 
     
(1)   No. 6 managers.

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Stock options and other share-based compensation

STOCK GRANTS
With the aim of improving motivation and loyalty of the managers of Eni SpA and its subsidiaries as defined in Article 2359 of the Civil Code through the linking of compensation to the attainment of preset individual and corporate objectives, making management participate in corporate risk and motivating them towards the creation of shareholder value and increasing at the same time their contribution to the management of the Company, in 2003 Eni started a stock grant scheme envisaging the offering of its own shares purchased under its buy back program (treasury shares) for no consideration to those managers of Eni
  who achieve corporate and individual objectives. Said scheme applied to the three year-period 2003-2005. Assignment vested within 45 days after the end of the third year from the date of the offer.
Under this stock grant plan, on December 31, 2006, a total of 1,873,600 grants were outstanding for the assignment of an equal amount of treasury shares (equal to 0.05% of capital stock) pertaining to 2003, 2004 and 2005 assignments as follows: (i) a total of 2.500 grants (fair value euro 11.20 per share) related to 2003, (ii) a total of 798,700 grants (fair value euro 14.57 per share) related to 2004 and (iii) a total of 1,072,400 grants (fair value euro 20.08 per share) related to 2005.
The following is a summary of stock grant activity for the years 2005 and 2006:

 

   

2005

 

2006

   
 
(euro)   Number
of shares
    Market price
in euro (a)
    Number
of shares
    Market price
in euro (a)
 
   
 
 
 
Stock grants as of January 1   3,112,200     18.461     3,127,200     23.460  
New rights granted   1,303,400     21.336     -     -  
Rights exercised in the period   (1,273,500 )   23.097     (1,236,400 )   23.933  
Rights cancelled in the period   (14,900 )   22.390     (17,200 )   23.338  
Stock grants outstanding of December 31   3,127,200     23.460     1,873,600     25.520  
of which exercisable at December 31   38,700     23.460     156,700     25.520  
   
 
 
 
     
(a)   Market price relating to new rights granted, rights exercised in the period and rights cancelled in the period corresponds to the average market value (arithmetic average of official prices recorded on Mercato Telematico Azionario in the month preceding: (i) the date of the resolution of the Board of Directors regarding the stock grants assignment; (ii) the date of the recording in the grantee's securities account of the emission/transfer of the shares granted; (iii) the date of the unilateral termination of employment for rights cancelled) weighted with the number of shares. Market price of stock grants at the beginning and at the end of the year is the price recorded at December 31.

 

The following table presents the amount of stock grants awarded to Eni’s CEO, General Managers and other managers with strategic responsibilities.    

 

       

Grants outstanding at beginning of the period

 

Grants exercised during the period

 

Grants outstanding at end of the period

       
 
 

Name

     

Number of grants

 

Average maturity in months

 

Number of grants

 

Average market price at date of exercise

 

Number of grants

 

Average maturity in months

       
 
 
 
 
 
Paolo Scaroni   CEO   -     -     -     -     -       -
Stefano Cao   General Manager of the E&P Division   43,700     21     14,700     24.117     29,000     15  
Domenico Dispenza (1)   General Manager   12,100     14     6,300     24.117     5,800     8  
    of the G&P Division   53,900  (2)   25     -     -     53,900  (2)   13  
Angelo Taraborrelli   General Manager of the R&M Division   28,100     24     6,300     24.117     21,800     17  
Other managers with strategic responsibilities (3)       111,400     21     60,500     23.478     50,900     15  
     
(1)   Appointed on January 1, 2006.
(2)   Snam Rete Gas' shares. These grants have been assigned by Snam Rete Gas to Domenico Dispenza who was Chairman of Snam Rete Gas until December 23, 2005.
(3)   No. 5 managers.

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STOCK OPTIONS
Eni offers managers of Eni SpA and its subsidiaries as defined in the Article 2359 of the Civil Code holding positions of significant responsibility for achieving profitability or strategic targets, the opportunity to acquire a shareholding in the company as an element of remuneration through the award of options for purchasing Eni treasury shares.
On May 25, 2006, the Sharehoders’ Meeting approved the 2006-2008 stock option plan and authorized the Board of Directors to make available a maximum amount of 30 million treasury shares (equal to 0.749% of the share capital) for the stock option plan.
This stock option plan foresees three annual awards. Unlike previous schemes, the 2006-2008 stock option plan introduced a performance condition upon which options can be exercised. At the end of each vesting period with a three-year duration, the Board of Directors determines the number of exercisable options, in a percentage ranging from 0% to 100% of the total amount awarded for each year of the plan, depending on the performance of Eni shares measured in terms of Total Shareholder Return as compared to that achieved by a panel of major international oil companies in terms of capitalization. On July 27, 2006, the Board of Directors approved:
  (i) the award pertaining to 2006 within the three-year period covered by the plan; (ii) its regulation; and (iii) the criteria to be followed in the identification of managers to whom the option will be assigned. The Board of Directors delegated to the CEO the task to identify eligible managers by the end of each year covered by the plan. Under this plan, 7,050,000 options were awarded pertaining to 2006 with a strike price of euro 23.119. Previous stock option plans provided that grantees had the right to purchase treasury shares in a 1 to 1 ratio after three years from the award, with a strike price calculated as the arithmetic average of official prices registered on the Mercato Telematico Azionario in the month preceding award or, if greater, as the average carrying cost of treasury shares held by Eni as of the date preceding the award.
At December 31, 2006, a total of 15,290,400 options were outstanding for the purchase of an equal amount of ordinary shares nominal value euro 1 of Eni SpA, carrying an average strike price of euro 21.022.
The weighted-average remaining contractual life of options outstanding at December 31, 2003, 2004, 2005 and 2006 was 4.6 years, 5.6 years, 6.6 years and 5.6 years, respectively.
The following is a summary of stock option activity for the years 2005 and 2006:

 

   

2005

 

2006

   
 
(euro)   Number of shares   Weighted average exercise price   Market price (a)   Number of shares   Weighted average exercise price   Market price (a)
   
 
 
 
 
 
Options as of January 1   11,789,00     15.111     18.461     13,379,600     17.705     23.460  
New options granted   4,818,500     22.512     22.512     7,050,000     23.119     23.119  
Options exercised in the period   (3,106,400 )   15.364     22.485     (4,943,200 )   15.111     23.511  
Options cancelled in the period   (121,500 )   16.530     23.100     (196,000 )   19.119     23.797  
Options outstanding as of December 31   13,379,600     17.705     23.460     15,290,400     21.022     25.520  
of which exercisable at December 31   1,540,600     16.104     23.460     1,622,900     16.190     25.520  
   

 

 

 

 

 

     
(a)   Market price relating to new rights assigned, rights exercised in the period and rights cancelled in the period corresponds to the average market value (arithmetic average of official prices recorded on Mercato Telematico Azionario in the month preceding: (i) the date of assignment; (ii) the date of the recording in the securities account of the managers to whom the options have been assigned; (iii) the date of the unilateral termination of employment for rights cancelled). Market price of shares referring to options as of the beginning and the end of the year, is the price recorded at December 31.

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The fair value of stock options granted during the years ended December 31, 2003, 2004, 2005, 2006 of euro 1.50, euro 2.01, euro 3.33 and euro 2.89 respectively, was calculated   applying the Black-Scholes method using the following assumptions:

 

   

2003

 

2004

 

2005

 

2006

   
 
 
 
Risk free interest rate  

(%)

 

3.16

 

3.21

 

2.51

 

4

Expected life  

(years)

 

8

 

8

 

8

 

6

Expected volatility  

(%)

 

22

 

19

 

21

 

16.8

Expected dividends  

(%)

 

5.35

 

4.5

 

3.98

 

5.26

       
 
 
 

 

The following table presents the amount of stock options awarded to Eni’s CEO, General Managers and other managers with strategic responsibilities.    

 

    CEO   General Manager E&P Division   General Manager G&P Division   General Manager R&M Division   Other managers with strategic responsibilities (1)
   
 
 
 
 
    Paolo Scaroni   Stefano Cao   Domenico Dispenza (2)   Angelo Taraborrelli    
   
 
 
 
 
Options outstanding at the beginning of the period:                                
- number of options       699,000     201,500   43,000   269,500  (3)   123,000   686,500
- average exercise price   (euro)   22.509     17.920   14.171   3.988     18.308   18.208
- average maturity in months       91     82   64   85     83   79
Options granted during the period                                
- number of options       681,000  (4)   175,500   122,500   -     115,000   552,500
- average exercise price   (euro)   23.100     23.100   23.100   -     23.100   23.100
- average maturity in months       72     72   72   -     72   72
Options exercised at the end of the period                                
- number of options       -     62,500   28,500   -     -   312,500
- average exercise price   (euro)   -     13.743   13.743   -     -   16.478
- average market price at date of exercise   (euro)   -     23.341   24.095   -     -   23.256
Options outstanding at the end of the period                                
- number of options       1,380,000     314,500   137,000   269,500     238,000   926,500
- average exercise price   (euro)   22.801     21.641   22.244   3.988     20.624   21.709
- average maturity in months       73     70   65   73     68   69
       

 
 
 

 
 
     
(1)   No. 9 managers.
(2)   Appointed on January 1, 2006.
(3)   Options on Snam Rete Gas shares: assigned by the company to Domenico Dispenza who held the position of Chairman of Snam Rete Gas until December 23, 2005.
(4)   The assignment to the CEO has been integrated by a deferred bonus linked to the market performance of Eni shares, to be paid after a three year period and corresponding to 96,000 options with a strike price of euro 23.100 and a vesting period of three years.

 

Overall remuneration of key management personnel
On the whole, remuneration of persons responsible of key positions in planning, direction and control functions of Eni Group companies, including executive and non-executive directors, general managers and
  other managers holding strategic responsibilities amounted to euro 23 million for 2006 consisting of: (i) fees and salaries for euro 16 million; (ii) post-employment benefits for euro 1 million; (iii) other long term benefits for euro 3 million; and (iv) fair value of stock grant/option for euro 3 million.

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Board Committees
The Board has instituted three committees with proposal and advisory functions. Their composition, tasks and functioning are defined by the Board of Directors in respect of the criteria established by the Eni Code. They are: a) the Internal Control Committee, b) the Compensation Committee and c) the International Oil Committee, composed almost exclusively of independent Directors.
In its meeting of June 1, 2005, the Board appointed the following directors as members of the Committees:
Internal Control Committee: Marco Reboa (Chairman, independent), Alberto Clô (independent), Renzo Costi (independent), Marco Pinto (non-executive) and Pierluigi Scibetta (independent);
Compensation Committee: Mario Resca (Chairman, independent), Renzo Costi (independent), Marco Pinto (non-executive) and Pierluigi Scibetta (independent);
International Oil Committee: Alberto Clô (Chairman, independent), Paolo Scaroni (CEO), Dario Fruscio (independent) and Marco Reboa (independent).
The Code, in line with the Borsa Italiana Code, suggests the creation of a “Nominating Committee”. The Board of Directors has not formed this Committee in consideration of the shareholding characteristics of Eni.

Internal Control Committee
The Internal Control Committee is entrusted with advisory and consulting tasks in respect of the Board in the area of monitoring general management issues.
In the course of 2006, the Internal Control Committee met 15 times, with an average participation of 80% of its members, and reviewed the following: (i) the 2006 audit plan prepared by Eni, Saipem and Snam Rete Gas internal audit functions and their progress; (ii) findings and results from Eni’s internal auditing interventions; (iii) initiatives undertaken and effects of measures applied in order to eliminate the weaknesses highlighted by Eni’s Internal Audit department; (iv) the essential features of the 2005 financial statements, making suggestions intended to improve the level of disclosure throgh meetings with top level representatives of administrative functions of the main Eni subsidiaries, chairmen of boards of statutory auditors and responsible partners from external audit companies; (v) Eni’s 2006 draft Half Year Report; (vi) the “Recommendations on the internal accounting control system” presented on 2004 financial statements by the external audit company; (vii) the external audit
  company reports on “Facts and circumstances of interest in the governance activity”; (viii) the situation of appointments of external auditors of main group companies, the recognition of costs incurred and the observations contained in the reports of external auditors pertaining to the financial statements of Eni’s subsidiaries; (ix) the proposal to integrate the task of Eni’s external auditors, to also include the certification of Eni’s internal control system, under Section 404 of the Sarbanes-Oxley Act (SOA) for fiscal year 2006, and the proposal extending the task of the external auditor currently in charge to audit the financial statements of Group companies and to certify the Group internal control system over financial reporting as well as all other admissible tasks for the 2007-2009 period; (x) the report on the implementation of SOA activities; (xi) the report presented by the Watch Structure established as required by Legislative Decree No. 231/2001; (xii) the general aspects of rules on recommendations received by Eni, which also include confidential or anonymous recommendations, issued also in respect of the Sarbanes-Oxley Act, and the periodic reports concerning the received recommendations; (xiii) the new organizational structure and the tasks of Eni Internal Audit function; (xiv) the reorganization of the Group supply activities; (xv) issues on hydrocarbon reserves and relevant classification criteria, also including accounting issues; (xvi) appointments of consultants and legal counsellors supporting the Company on legal matters for the 2005-2006 two year period; (xvii) antitrust procedures and the recognition of the relevant provisions to the risk reserve; (xviii) the reports on additional information submitted to the SEC and accounting treatment of the merger of Enifin with the parent company Eni; (xix) the report on Eni administrative and accounting organization to be submitted to the Board of Directors.
The Internal Audit Manager is the secretary of the Committee. In its meeting of March 16, 2007, the Board of Directors, as proposed by the CEO, in agreement with the Chairman and after asking the Internal Control Committee for its opinion, entrusted the Internal Audit Manager as manager delegated for the internal control.

Compensation Committee
The Compensation Committee, established by the Board of Directors in 1996, is entrusted with proposing tasks with respect to the Board on the matters of compensation of the Chairman and CEO as well as of the Board Committees members, and following the indications of the CEO, on the following: (i) stock-based incentive plans; (ii) the definition of the

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criteria for the compensation of top managers of the Group; (iii) the setting of objectives and the evaluation of results of performance and incentive plans.
In 2006, the Compensation Committee met nine times with an average participation of 96% of its members, and accomplished the following:
(i) verified functions and tasks of the Committee, defined by the new regulation approved by the Board of Directors in June 2005 (available on Eni’s website), in accordance with the national and international corporate governance principles, confirming their substantial alignment with international and national standards; (ii) examined the objectives of the 2006 performance and incentive plan and appraised 2005 results, to be submitted to the Board of Directors for approval; (iii) examined the revised long-term incentive system for managers, and drafted a proposal based on which the Board of Directors requested the Shareholders’ Meeting’s approval of the 2006-2008 stock option plan and the authorization to use treasury shares for servicing the stock option plan; (iv) examined the issue of the insurance against professional risks included in agreements for Eni managers, extended to Directors and Statutory Auditors, as approved by the Board of Directors in its meeting of March 30, 2006, and the issue of the insurance against managerial risks, on which the Shareholders’ Meeting’s approval has been requested; (v) examined the Chairman variable compensation and drafted a proposal for determining the variable part of the remuneration of the Chairman and CEO based on 2005 performance to be submitted to the Board of Directors; (vi) examined the benchmarks for top management remuneration, the criteria of the annual remuneration policy, as well as the implementation of incentive plans for the year and in the long-term in order to draft a proposal to submit to the Board of Directors; (vii) examined the compensation to be attributed to the Directors, related to functions and activities performed in their role as members of the Committees established by the Board, in order to draft a proposal approved by the Board of Directors’ meeting of July 27, 2006; (viii) examined the impact of the new stock-based incentive scheme on CEO compensation, and drafted an integration proposal in order to maintain the incentive level established in 2005, to be submitted to the Board of Directors (see “Stock options and other share-based compensation”).
In 2006, the Committee appointed external consultants to acquire analysis and advice on its specific matters.
  International Oil Committee
The International Oil Committee is entrusted with the monitoring of trends in oil markets and the study of their aspects.
In 2006 the International Oil Committee met five times with a 75% participation of its members.
The first meeting concerned trends and conditions of the oil and gas industry, as well as the key variables of the energy scenarios for Eni’s four-year strategic plan.
The other meetings concerned the analysis of worldwide energy market prospects to 2020, to identify the main issues and challenges to be addressed in Eni Master Plan – a key document in the planning process defining Eni industrial strategies.
In particular, the meetings dealt with: (i) worldwide energy consumption trends to 2020 – discussed in two meetings – aimed at identifying fundamentals, underlying assumptions and possible uncertainties in consumption trends in the most important world areas; (ii) a survey of the supply of natural gas in the world and (iii) a survey of the worldwide oil supply, highlighting hydrocarbons and infrastructure development trends, in relation to the industrial and market trends in the next 15 years.

Board of Statutory Auditors and other control entities

Board of Statutory Auditors
The Board of Statutory Auditors, in accordance with Legislative Decree No. 58/1998 (TUF), monitors: (i) the respect of laws and of Eni’s memorandum of association; (ii) the respect of the principles of proper administration; (iii) the adequacy of the company’s organizational structure, for the parts covered by the Board's responsibility, of its internal control system and administration and accounting systems as well as the reliability of the latter in fairly representing the management of the company; (iv) the adequacy of instructions conveyed by the parent company to its subsidiaries according to Article 114, paragraph 2 of the above mentioned decree; (v) the actual implementation of corporate governance rules foreseen by the codes of conduct prepared by market regulators and the associations the company belongs to, that the company publicly declares to respect.
In accordance with the Eni Code, in line with the Borsa Italiana Code, the Board of Statutory Auditors monitors the independence of the external auditing firm, verifying both the compliance with the provisions of applicable laws and regulations governing the matter, and the nature and extent of services other than the accounting

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control provided to Eni by the auditing firm and the entities belonging to its network.
According to the TUF (as amended by Legislative Decree No. 303/2006), the Board of Statutory Auditors drafts a proposal regarding the appointment of the external auditors and their fee to be submitted to the Shareholders’ Meeting for approval.
The Board of Directors, in its meeting of March 22, 2005, in accordance with the provision of the SEC Rule 10A-3 for non-US companies listed on US stock exchanges, elected the Board of Statutory Auditors to fulfill the role of the audit committee in US companies under the Sarbanes-Oxley Act and SEC rules, within the limits set by Italian legislation from June 1, 2005. On June 15, 2005, the Board of Statutory Auditors approved the regulation for carrying out the functions attributed to the audit committee under US laws. This regulation is published on Eni’s website.

Composition and appointment
The Board of Statutory Auditors is comprised of five auditors and two alternate auditors, appointed by the Shareholders’ Meeting for a three-year term.
On May 27, 2005, Eni’s Shareholders’ Meeting appointed the following statutory auditors for a three-year period and however until the Shareholders’ Meeting approving financial statements for fiscal year 2007: Paolo Andrea Colombo (Chairman), Filippo Duodo, Edoardo Grisolia, Riccardo Perotta and Giorgio Silva. Francesco Bilotti and Massimo Gentile are alternate auditors. A curriculum of these auditors is published on Eni’s website. The same Meeting also determined the yearly compensation of the Chairman of the Board of Statutory Auditors and each Auditor amounting to euro 115,000 and euro 80,000 respectively.
Paolo Andrea Colombo, Filippo Duodo, Edoardo Grisolia and Francesco Bilotti were candidates in the list presented by the Ministry of Economy and Finance; Riccardo Perotta, Giorgio Silva and Massimo Gentile were candidates in the list presented by institutional investors coordinated by Fineco Asset Management SpA.
Statutory Auditors are appointed in accordance with Eni’s By-laws with a list vote; at least two auditors and one substitute are chosen from minority candidates.
According to Article 28.2 of Eni’s By-laws, as revised by the Shareholders’ Meeting of May 25, 2006, to implement the provision of Law No. 262 of December 28, 2005 (law on the protection of savings), the Shareholders’ Meeting elects Chairman of the Board of Statutory Auditors a member elected from a list other than the one obtaining the majority of votes; this prescription will be applied in the next Board election.
The lists of candidates include declarations made by
  the candidates on the possession of independence and expertise requirements prescribed by applicable regulation and a professional resume of each candidate, must be filed at the company’s headquarters at least 10 days before the date of the Shareholders’ Meeting on first call and are published in national newspapers.

Expertise and independence
In accordance with the TUF, Statutory Auditors have to possess the specific requirements of independence, and the professional and honorability requirements as prescribed by a regulation of the Minister of Justice.
As also reported in the Code, the Statutory Auditors shall act with autonomy and independence also vis-à-vis the shareholders who elected them.
As for professional qualifications of the candidates, Article 28 of Eni’s By-laws, in line with the said Decree of the Minister of Justice, foresees that the professional requirements can also be acquired with at least three years of professional experience or by teaching business law, business administration and finance, as well as at least a three year experience in a managerial position in geological or engineering businesses.
Eni’s auditors are all chartered auditors.
Article 28 of Eni’s By-laws also prohibits the appointment as statutory auditor of persons that are statutory auditors or members of the supervisory board or members of the management control committee of at least five companies with registered securities in regulated markets not subsidiaries of Eni SpA. In case such persons are elected, their task is terminated.
This prescription should be replaced by a Consob regulation defining the maximum allowed number of appointments of a statutory auditor in line with the TUF.
In its meeting of March 16, 2007, the Board of Statutory Auditors verified that all its members complied with the independence criteria prescribed by the rules of the Eni Code intended to ensure the Statutory Auditors’ possession of required independence after their appointment, also based on the criteria defined by the Code for the members of the Board of Directors.

Meetings and functioning
Statutory auditors receive information on all issues on the agenda of the Board of Directors at the same time as the Directors.
In line with the provisions of the Eni Code, an Auditor who has an interest, either own or on behalf of third parties, in a certain transaction of the issuer, shall inform the Board of Directors and the other Auditors.
In 2006, the Board met 20 times with an average participation of 88% of its members.

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The table attached at the end of this section indicates, the percentage of participation of each auditor to the Board of Auditors meetings.

Further Auditors' appointments
Based on information received, information on positions held by the members of Eni’s Board of Statutory Auditors in other Boards of Directors and Boards of Statutory Auditors of listed companies, also abroad, financial, banking, insurance or large companies is provided below.
The curriculum of each Auditor is available on Eni’s website.

PAOLO ANDREA COLOMBO
Chairman of Sintesi SpA, independent Director of Mediaset SpA, Interbanca SpA, Iniziative Gestione Investimenti SpA, RCS Quotidiani SpA, SIAS SpA, Director of Versace SpA. Chairman of the Board of Statutory Auditors of Ansaldo STS and Saipem SpA. Auditor of Aviva SpA, Lottomatica SpA and Sirti SpA.

FILIPPO DUODO
Chairman of the Board of Statutory Auditors of Banca Meridiana SpA. Auditor of Benetton Group SpA.

RICCARDO PEROTTA
Chairman of the Board of Statutory Auditors of Snam Rete Gas SpA and Gewiss SpA, Auditor of ECS International Italia SpA.

GIORGIO SILVA
Auditor of Luxottica SpA and RCS Mediagroup SpA.

External Auditors
As provided for by Italian law, the auditing of financial statements is entrusted to external auditors registered on the register held by Consob. The external auditor is appointed by the Shareholders’ Meeting. Eni’s external auditor, PricewaterhouseCoopers SpA, was appointed by the Shareholders’ Meeting of May 28, 2004 for a three-year term ending with the Meeting approving financial statements for 2006.
Financial statements of Eni subsidiaries are audited, mainly by PricewaterhouseCoopers. In order to express its opinion on Eni’s consolidated financial statements PricewaterhouseCoopers took the responsibility of the audit activities performed by other auditors on certain Eni fully consolidated subsidiaries representing, however, a negligible part of Eni’s consolidated assets and revenues.
Eni’s external auditor and the companies belonging to its network are not to be entrusted with tasks not pertaining to audit activities, except for rare and
  motivated cases for tasks – not prohibited by Consob and the Sarbanes-Oxley Act – subject to authorization by Eni’s Board of Statutory Auditors and to approval by the Board of Directors of Eni Group companies upon favorable opinion of their Board of Statutory Auditors. Eni’s Board of Statutory Auditors must be informed of all tasks entrusted to external auditors by Eni Group companies.

Other auditing
The accounts of the parent company Eni SpA are subject also to the review of the Italian Court of Accounts. The relevant activity is performed by the Magistrate delegated to control, Lucio Todaro Marescotti (alternate Magistrate Angelo Antonio Parente), replacing Luigi Schiavello, as decided on July 19-20, 2006, by the Governing Council of the Italian Court of Accounts.
The Magistrate delegated to control attends the meetings of the Board of Directors, the Board of Statutory Auditors and the Internal Control Committee.

Internal controls
Eni is aware that financial information plays a crucial role in the creation and maintenance of satisfying relationships between the company and its increasingly wide area of stakeholders, and contributes, as well as the group performance, to the creation of value for the shareholders.
Eni is also aware that investors rely on Eni managers and employees respecting procedures and rules of the company’s internal control system.
In this area a special relevance is attribuited to Eni’s Code of Conduct that identifies the fundamental values for the deployment of Eni activities in the formal and substantial legitimacy of behavior of its employees at any organizational level, the transparency of accounts and disclosure, and the spreading of a control oriented attitude.
The Board of Directors evaluates the consistency of the internal control system with the company structure and characteristics. The CEO monitors the functionality of the internal control system, supported by the manager in charge of the internal control and by the Internal Audit department.
In particular, the Board of Directors is assisted by the Internal Control Committee in the performance of the tasks related to: (i) defining the guidelines for the company’s internal control system intended to ensure that the main company risks are correctly identified, measured, managed and monitored, also determining whether such risks are compatible with a sound and a correct management of the company; (ii) annually evaluating the suitability, effectiveness and

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efficient operation of the internal control system; (iii) disclosing the key elements of the internal control system, and evaluating its overall adequacy in the annual report on corporate governance. In performing those tasks, the Board of Directors refers to available conceptual models and domestic and international best practices. Special attention is paid to organization and management models adopted according to Legislative Decree No. 231/2001 and to the Code of Conduct.
In line with these principles, Eni adopted regulations for the preparation of financial statements of the Group companies and the collection of information necessary for timely and fair disclosure in quarterly and yearly reports in accordance with generally accepted rules and accounting standards, ensuring also uniformity of behavior, an essential element for the provision of proper financial information on the Group.
With the aim of ensuring the effective and correct enactment of such rules, principles and standards and of general rules governing processes for information to be recorded, processed, summarized and reported, Eni adopted an internal control system designed with the aim of providing investors and markets with fair, complete and timely information.
Eni internal control system has been designed in accordance with the provisions of the Sarbanes-Oxley Act of 2002 (SOA) which Eni has to comply with as its securities are listed on the New York Stock Exchange. Such control system was designed in accordance with two fundamental principles:
  • to extend control to all the levels of the organizational structure, consistently with the operating task entrusted to each level;
  • sustainability of controls in the long term, so as to ensure that the performance of controls is increasingly integrated in and compatible with operating needs; for this purpose, specific controls have been selected in order to identify such critical controls as to mitigate the level of risk.

The objectives of the internal control system have been defined consistently with applicable provisions of US rules distinguishing two systemic components:

  • disclosure controls and procedures;
  • internal control over financial reporting.

Disclosure controls and procedures are defined as controls and other procedures of the company that are designed to ensure that information required to be disclosed by the company in its reports is collected and communicated to Eni management, including Eni’s CEO and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

  Internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.
Eni’s internal control over financial reporting has been designed to be consistent with the Internal Control-Integrated Framework created and published by the Committee of Sponsoring Organizations of the Treadway Commission and comprises five interrelated components: control environment, risk assessment, control activities, information and communication, and monitoring. Such components in relation to their own features operate at entity level (Group, business segment, divisions, subsidiary) and/or at a process level, including both operational and financial administration process (transaction, evaluation processes and closing the books).
The key objective of internal control over financial reporting is to mitigate risks due to negligence and risks of fraud, significantly impacting financial statements. In addition, a specific risk assessment has been performed on fraud risks, and from this anti-fraud measures and controls have been designed.
Management has developed its own assessment procedures to evaluate the design of Eni’s internal control over financial reporting and its operating effectiveness. To that end, management has implemented ongoing monitoring activities entrusted to managers who are responsible of conducting primary processes or activities, and separate evaluations have been entrusted to Eni’s Internal Audit department. This department operates according to a preset plan of interventions defining scope and objectives of each intervention.
Outcomes from all monitoring activities are reported periodically in order to ascertain the state of Eni’s internal control over financial reporting. All levels of Eni’s organizational structure are involved in this reporting process.
A primary role in Eni’s internal control over financial reporting is played by the Internal Audit department, directly reporting to the CEO and to the Board of Statutory Auditors in its quality of audit committee under the SOA.
The Internal Audit Manager, in his/her role as responsible for internal control activities, reports to the CEO, to Eni’s Internal Control Committee and to the Board of Statutory Auditors. Among the tasks entrusted to the Internal Audit department are: (i) to ensure implementation of the following activities: vigilance activity as required by Legislative Decree No. 231/2001; separate evaluations as required by the SOA,

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operational, financial, information technology and fraud auditing activities on behalf of Eni divisions and Eni’s fully-owned subsidiaries lacking their own Internal Audit departments; (ii) to update Eni’s system for identifying, classifying and assessing risk areas in order to plan control activities; (iii) to implement planned and non-planned control activities, and to identify possible gaps with respect to adopted conceptual models, also making proposals on corrective measures and monitoring subsequent follow-up activities; (iv) to maintain relationships with external auditors; (v) to maintain relationships with and ensure information flows to the Watch Structure, the Internal Control Committee and the Board of Statutory Auditors; (vi) to ensure the management of the recommendations received by Eni, also under an anonymous form, during the internal preliminary investigations and supporting the entrusted company bodies in their evaluation process, always in full compliance with Eni procedures.
The integrated auditing plan and the outcomes of the activities performed are evaluated by the Internal Control Committee, the Board of Statutory Auditors, and the Watch Structure within the boundaries of the matters covered by Legislative Decree No. 231/2001.
The Internal Audit department and the external auditors have complete access to data, information and documentation which can support the performance of auditing activities.

Legislative Decree No. 231/2001
In its meetings of December 15, 2003 and January 28, 2004 the Board of Directors approved a “Model for organization, management and control according to Legislative Decree No. 231/2001” and established a Watch Structure. Legislative Decree No. 231/2001 states the administrative responsibility of entities such as companies and partnerships, according to Article 11 of Law No. 300 of September 29, 2000. The principles of the “231 model” are published on Eni’s website. The criteria for the preparation of this model are those included in a guidebook prepared by Confindustria (the Italian association of industrial companies) as verified by the Ministry of Justice as required by the same Decree. The model was transmitted to all Group companies for application.

Transactions in which a director has an interest
and transactions with related parties

In accordance with the TUF and with Article 23.3 of Eni’s By-laws, the Directors shall timely inform the Board of Statutory Auditors on transactions in which they have an interest.
  During each Board of Directors’ meeting, the Chairman expressly asks the Directors to declare any of their potential interest in transactions on the agenda.
The Eni Code, in accordance with the Borsa Italiana Code, foresees the adoption, by the Board of Directors, of measures ensuring that transactions in which a director has an interest, directly or on behalf of third parties, and all transactions carried out with related parties, are performed in a transparent way and meet criteria of substantial and procedural fairness.
In addition, the Eni Code foresees a specific opinion of the Internal Control Committee on the rules adopted by the Board of Directors.
Preparation of a procedure regarding transactions with related parties is underway; however its finalization is stalling due to the circumstance that Italian listed companies are awaiting the emission on part of Consob of certain guidelines that Article 2391-bis of the Civil Code assigns to Consob. Pending the emission of such guidelines, Eni’s internal rules provide that transactions with related parties be submitted to the Board of Directors, even though of amounts lower than the materiality threshold set for the transactions to be approved by the Board;
The Board of Directors’ resolution defining the powers of the Board itself points out the needs to pay particular attention to those situations in which a director has an interest and to transactions with related parties.
Moreover, Eni is committed to observing principles as defined in the Borsa Italiana Code regarding such persons holding significant positions in the share capital of listed companies and in particular respecting their managerial autonomy.
In the ordinary course of its business, Eni enters into transactions concerning the exchange of goods, provision of services and financing with related parties as defined by IAS 24. These include non consolidated subsidiaries and affiliates as well other companies owned or controlled by the Italian Government. All such transactions are conducted on an arm’s length basis and in the interest of Eni Group companies.
Eni’s Directors, General Managers and managers with strategic responsibilities disclose every six months any transactions with Eni SpA and its subsidiaries that require disclosure under IAS 24.
Amounts and types of trade and financial transactions with related parties and their impact on consolidated earnings and cash flow, and on the Group’s assets and financial condition are reported in Note 33 to the consolidated financial statements.

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Significant differences in corporate governance practices as per Section 303A.11 of the New York Stock Exchange Listed Company Manual
Corporate governance As discussed above, Eni’s organizational structure follows the traditional Italian model of companies which provides for two main separate corporate bodies, the Board of Directors and the Board of Statutory Auditors to whom management and monitoring duties are respectively entrusted. This model differs from the U.S. unitary model which provides for the Board of Directors as the sole corporate body responsible for management and for audit committee established within the same Board
for monitoring.
Below is a description of the most significant differences between corporate governance practices followed by U.S. domestic companies under the NYSE standards and those followed by Eni.

INDEPENDENT DIRECTORS
NYSE Standards Under NYSE standards listed U.S. companies’ Boards must have a majority of independent directors. A director qualifies as independent when the Board affirmatively determines that such director does not have a material relationship with the listed company (and its subsidiaries), either directly, or indirectly. In particular, a director may not deemed independent if he/she or an immediate family member has a certain specific relationship with the issuer, its auditors or companies that have material business relationships with the issuer (e.g., he/she is an employee of the issuer or a partner of the auditor). In addition, a director cannot be considered independent in the three-year “cooling-off” period following the termination of any relationship that compromised a director’s independence.

Eni Standards In Italy, the Borsa Italiana Code recommends that the Board of Directors includes an adequate number of independent non-executive directors "in the sense that they do not maintain, nor have recently maintained, directly or indirectly, any business relationships with the issuer or persons linked to the issuer, of such a significance as to influence their autonomous judgement".
The directors’ independence shall be periodically assessed by the Board of Directors.
The results of the assessments of the Board shall be communicated to the market.
The Board of Directors shall evaluate the independence of its non-executive members having regard more to the contents than to the form and keeping in mind that a director usually does not appear independent in the
  following events, to be considered merely as an example and not limited to:
a) if he/she controls, directly or indirectly, the issuer also through subsidiaries, trustees or through a third party, or is able to exercise over the issuer dominant influence, or participates in a shareholders’ agreement through which one or more persons may exercise a control or considerable influence over the issuer;
b) if he/she is, or has been in the preceding three fiscal years, a relevant representative of the issuer, of a subsidiary having strategic relevance or of a company under common control with the issuer, or of a company or entity controlling the issuer or able to exercise over the same a considerable influence, also jointly with others through a shareholders’ agreement;
c) if he/she has, or had in the preceding fiscal year, directly or indirectly (e.g., through subsidiaries or companies of which he/she is a significant representative, or in the capacity of partner of a professional firm or of a consulting company) a significant commercial, financial or professional relationship:
- with the issuer, one of its subsidiaries, or any of its significant representatives;
- with a subject who, jointly with others through a shareholders’ agreement, controls the issuer, or – in case of a company or an entity – with the relevant significant representatives;
- or is, or has been in the preceding three fiscal years, an employee of the abovementioned subjects;
d) if he/she receives, or has received in the preceding three fiscal years, from the issuer or a subsidiary or holding company of the issuer, a significant additional remuneration compared to the “fixed” remuneration of non-executive director of the issuer, including the participation in incentive plans linked to the company’s performance, including stock option plans;
e) if he/she was a director of the issuer for more than nine years in the last 12 years;
f) if he/she is vested with the office of executive director in another company in which an executive director of the issuer holds the office of director;
g) if he/she is shareholder or quotaholder or director of a legal entity belonging to the same network as the company appointed for the accounting audit of the issuer;
h) if he/she is a close relative of a person who is in any of the positions listed in the above paragraphs.
The Eni Code foresees further independence requirements, in line with the ones provided by the

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Borsa Italiana Code. In its meeting of February 22, 2007, Eni’s Board of Directors judged that six out of eight of its non-executive members comply with the independence standards, set by the Eni Code. Non-executive Director Marco Pinto is an employee of the Ministry of Economy and Finance.

MEETINGS OF NON EXECUTIVE DIRECTORS
NYSE Standards Non-executive directors, including those who are not independent, must meet at regularly scheduled executive sessions without management. In addition, if the group of non-executive directors includes directors who are not independent, independent directors should meet separately at least once a year.

Eni Standards Neither Eni’s non-executive directors nor Eni’s independent directors must meet separately,under the Code’s corporate governance rules.

AUDIT COMMITTEE
NYSE Standards Listed U.S. companies must have an audit committee that satisfies the requirements of Rule 10A-3 under the Securities Exchange Act of 1934 and that complies with the further provisions of the Sarbanes-Oxley Act and of Section 303A.07 of the NYSE Listed Company Manual.

Eni Standards In its meeting of March 22, 2005, Eni’s Board of Directors, making use of the exemption provided by Rule 10A-3 for non-U.S. private issuers, has identified the Board of Statutory Auditors as the body that, starting from June 1, 2005, is performing the functions required by the SEC rules and the Sarbanes-Oxley Act to be performed by the audit committees of non-U.S. companies listed on the NYSE (see paragraph “Board of Statutory Auditors” earlier). Under Section 303A.07 of the NYSE listed Company Manual audit committees of U.S. companies have further functions and responsibilities which are not mandatory for non-U.S. private issuers and which therefore are not included in the list of functions shown in the paragraph referenced above.

NOMINATING/CORPORATE GOVERNANCE COMMITTEE
NYSE standards U.S. listed companies must have a nominating/corporate governance committee (or equivalent body) composed entirely of independent directors that are entrusted, among others, with the responsibility to identify individuals qualified to become board members and to select or recommend director nominees for submission to the Shareholders’ Meeting, as well as to develop and recommend to the Board of Directors a set of corporate governance guidelines.
  Eni Standards This provision is not applicable to non-U.S. private issuers. The Code allows listed companies to have within the Board of Directors a committee for directors’ nominees proposals, above all when the Board of Directors detects difficulties in the shareholders’ submission of nominees proposals, as could happen in publicly owned companies. Eni has not set up a nominating committee, considering the nature of its shareholding as well as the circumstance that, under Eni’s By-laws, directors are appointed by the Shareholders’ Meeting based on lists presented by shareholders or by the Board of Directors.


The shareholders
The Shareholders’ Meeting
During meetings, shareholders can request information on issues in the agenda. Information is provided within the limits of confidentiality, taking account of applicable rules regulating the matter of price sensitive information.
With the aim of facilitating the attendance of shareholders, calls for meetings are published in Italian and foreign newspapers, Eni’s By-laws allow vote by correspondence and the collection of powers of attorney in Articles 13 and 14.
On December 4, 1998, Eni approved a regulation for its meetings, available on Eni’s website, in order to guarantee an efficient deployment of meetings, in particular the right of each shareholder to express his opinion on the items in the agenda.
The Shareholders’ Meeting held on May 25, 2006, in order to align Eni’s By-laws to the prescriptions of the TUF regulating the protection of investors, modified the By-laws stating that all the shareholders representing also with others, at least 1/40 of the share capital, can ask to add items to the agenda, within five days of the publication of the convening notice.

Eni’s shareholders
Eni SpA’s share capital at December 31, 2006, amounted to euro 4,005,358,876 fully paid and was represented by 4,005,358,876 ordinary shares, at a nominal value euro 1 each. Shares are not divisible and give right to one vote. Shareholders can exercise the rights provided by the law.
In accordance with Article 6 of Eni’s By-laws, no shareholder, excepted the Italian Government, can directly or indirectly own more than 3% of Eni SpA’s share capital; the shares held above this limit do not allow to exercise the rights exceeding the 3% threshold.
In 1995 Eni issued a sponsored ADR (American Depositary Receipts) program directed to U.S.

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investors. One ADR is equal to two Eni ordinary shares; ADRs are listed on the New York Stock Exchange. Based on information available and received in accordance with Consob Decision   No. 11971/1999, as of December 31, 2006, shareholders holding more than 2% of Eni’s share capital were the following:

 

Shareholders   Shares held   % of capital
   
 
Ministry of Economy and Finance   813,443,277   20.31
Cassa Depositi e Prestiti SpA   400,288,338   9.99
Eni SpA (own shares)   324,959,866   8.11
   
 

 

Shareholders by area            
Shareholders   Number of shareholders   Number of shares   % of capital (1)
   
 
 
Italy   337,133   2,499,529,005   62.40
UK and Ireland   1,160   208,488,751   5.21
Other EU   4,270   511,666,488   12.77
USA and Canada   1,848   327,231,932   8.17
Rest of world   1,387   146,093,376   3.65
Own shares at the dividend date       312,264,429   7.80
Other       84,895   ..
Total   345,798   4,005,358,876   100.00
   
 
 
     
(1)   At the dividend payment date, June 22, 2006 (ex-dividend date was June 19, 2006).

 

Shareholders by amount of shares held            
Shareholders   Number of shareholders   Number of shares   % of capital (1)
   
 
 
>10%   1   813,443,277   20.31
3%-10   1   400,288,338   9.99
2%-3% (2)   1   93,040,000   2.32
1%-2%   8   510,288,948   12.74
0.5%-1%   9   218,486,106   5.46
0.3%-0.5%   15   238,443,980   5.95
0.1%-0.3%   56   377,681,072   9.43
= 0.1%   345,707   1,041,337,831   26.00
Own shares at the dividend date       312,264,429   7.80
Other       84,895   ..
Total   345,798   4,005,358,876   100.00
             
     
(1)   At the dividend payment date June 22, 2006 (ex-dividend date was June 19, 2006).
(2)   Shareholder Banca Intesa informed that it reduced its interest from 2.32 to 0.57%.

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Special powers of the State - golden share
Under Article 6.1 of Eni’s By-laws only the Italian State can hold shares representing more than 3% of Eni’s share capital.
Eni’s By-laws in Article 6.2 attribute to the Minister for Economy and Finance, in agreement with the Minister of Economic Development, the following special powers to be used in compliance with the criteria indicated in the Decree of the President of the Council of Ministers of June 10, 2004: (a) opposition with respect to the acquisition of material shareholdings representing 3% of the share capital of Eni SpA having the right to vote at ordinary Shareholders’ Meetings. Such opposition is required to be expressed within 10 days of the date of the notice to be filed by the Board of Directors at the time a request is made for registration in the Shareholder’ register, should the transaction be considered prejudicial to vital interests of the State; (b) opposition with respect to the subscription of shareholders’ agreements or other arrangements (as defined by Article 122 of Legislative Decree No. 58 of February 24, 1998) whereby 3% or more of the share capital of Eni SpA having the right to vote at ordinary Shareholders’ Meetings is involved; (c) veto power – duly motivated by the case of prejudice to the interests of the State – with respect to shareholders’ resolutions to dissolve Eni SpA, to transfer the business, to merger or to demerger, to transfer the registered office of Eni SpA outside Italy, to change the corporate purposes or to amend or modify any of the special powers described in this section; (d) appointment of a Board member without voting right.
Law No. 266 of December 23, 2005 (Budget Law) in Article 1, paragraphs 381 to 384 in order to favor the process of privatization of and the diffusion among the public of shareholdings in companies in which the State holds significant stakes, introduced the option to include in the by-laws of listed companies formerly entirely owned by the State, as in the case of Eni SpA, regulations providing the issuance of shares and securities also at par value with the right to vote at ordinary and extraordinary Shareholders’ Meetings in favor of one or more shareholders identified also in terms of the number of shares held. The introduction of these norms in Eni’s By-laws, subject to approval by the EU, will entail the cancellation of the 3% threshold to individual shareholdings, except for the State, as contained in Article 6.2 of Eni’s By-laws.

Eni’s By-laws modifications
Legislative Decree No. 303/2006 introduced changes to the law on protection of savings. In the meeting of March 29, 2007, the Board of Directors convened the
  Shareholders’ Meeting also in extraordinary session, to approve the changes to Eni’s By-laws, that align the by-laws to the said Decree.
Adjustments introduced by the law on protection of savings had already been adopted by the May 25, 2006 Shareholders’ Meeting.

Shareholder and investor relations
In concert with the launch of its privatization process, Eni adopted a communication policy, confirmed by the Code of Conduct, aimed at promoting an ongoing dialogue with institutional investors, shareholders and the markets to ensure systematic dissemination of exhaustive complete, transparent, selective and prompt information on its activities, with the sole limitation imposed by the confidential nature of certain information. Information made available to investors, markets and the press is provided in the form of press releases, regular meetings with institutional investors and the financial community and the press, in addition to general documentation released and constantly updated on Eni’s website. Relations with individual investors, institutional investors, shareholders and the press are handled by dedicated Eni departments.
Relations with investors and financial analysts are held by the Investor Relations manager. Information is available on Eni’s website and can be requested by sending an email to investor.relations@eni.it.
Relations with the press are held by the press manager.
Relations with shareholders are held by the Corporate Secretary office. Information is available on Eni’s website and can be requested by sending an email to segreteriasocietaria.azionisti@eni.it or calling the toll-free number 800.940.924 (Outside Italy 800.11.22.3456).
Information regarding periodic reports and major events/transactions are promptly made available to the public, and are also published on Eni’s website. A specific section of Eni’s site contains all press releases, procedures concerning corporate governance, presentations provided in meetings with the press and financial analysts, notices to shareholders and bond holders and information concerning shareholders’ and bond holders’ meetings, including proceeds thereof. Documents available to the public are mailed on request free of charge.

Handling of company information

On February 28, 2006, Eni’s Board of Directors updated the “Procedure for the disclosure of information to the market concerning Group

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activities” approved on December 18, 2002 and published on Eni’s website. The procedure acknowledges Consob guidelines and the “Guidelines for information to the market” issued in June 2002 by the Ref Forum on company information and those included in the laws implementing the European directive on market abuse, defines the requirements for disclosure to the public of price sensitive events (materiality, clarity, homogeneity, information symmetry, consistency and timeliness) and the information flows for acquiring data from Group companies and providing adequate and timely information to the Board and the market on price sensitive events. It also contains sanctions applied in case of violation of its rules in accordance with the crimes identified and sanctioned by the new law on the protection of savings.
Eni’s Code of Conduct defines confidentiality duties upheld by Group employees relating to the treatment of sensitive information.
Directors and Auditors ensure the confidentiality of documents and information acquired during their tasks and respect the procedure defined by Eni for the treatment of information and for the and the disclosure of information to the market.

Register of the persons having access to privileged information

On February 28, 2006, the Board of Directors approved a procedure concerning the creation and updating a register of persons with a right to access privileged information at Eni, as provided for by Article 115-bis of Legislative Decree No. 58 of February 24, 1998.
The procedure implementing Consob Decision on listed issuing companies, states:
(i) terms and procedures for the recording and possible cancellation of the persons that, due to their professional activity or functions performed on behalf of Eni, have access to privileged information; (ii) terms and procedures of information of said persons of their recording or cancellation and relevant reasons.
The procedure is in force from April 1, 2006 and was updated on September 29, 2006 to take into account the Consob position expressed on March 28, 2006. The procedure is published on Eni's website.
 

Internal Dealing

On February 28, 2006, the Board of Directors approved the “Internal dealing procedure” for the identification of relevant persons and the communication of transactions involving financial instruments issued by Eni SpA and its listed subsidiaries made by these persons, which substitutes the Internal Dealing Code approved by the Board on December 18, 2002.
The procedure implements the provisions of Article 114, paragraph 7 of Legislative Decree No. 58 of February 24, 1998.
Eni’s procedure, implementing Consob Decision on listed issuing companies: (i) identifies relevant persons: (ii) defines the transactions involving financial instruments issued by Eni SpA; (iii) determines the terms and conditions for the disclosure to the public of such information.
The procedure states that managers having regular access to privileged information, during specific periods of the year (blocking periods), are not allowed to buy or sell shares.
The procedure went into effect on April 1, 2006, and was updated on September 29, 2006 to take into account the Consob position expressed on March 28, 2006. The procedure is published on Eni's website.

* * *

Follow the tables included in the “Handbook for the preparation of the report on corporate governance” issued by Assonime and Emittente Titoli SpA in March 2004.

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Structure of the Board of Directors and its Committees            

Board of Directors

 

Internal Control
Committee

 

Compensation
Committee

 

International Oil
Committee


 
 
 

Members

     

executive

 

non executive

 

independent

 

% attendance

 

other appointments (1)

 

members

 

% attendance

 

members

 

% attendance

 

members

 

% attendance




 
 
 
 
 
 
 
 
 
 
 
Chairman                                              
Roberto Poli           

X

 

  

 

100

 

4

                       
CEO                                              
Paolo Scaroni    

X

         

100

 

4

                 

X

 

40

Directors                                              
Alberto Clô (*)        

X

 

X

 

94

 

4

 

X

 

87

         

X

 

100

Renzo Costi (*)        

X

 

X

 

69

     

X

 

67

 

X

 

100

       
Dario Fruscio        

X

 

X

 

56

                     

X

 

60

Marco Pinto        

X

     

81

     

X

 

60

 

X

 

78

       
Marco Reboa (*)        

X

 

X

 

100

 

5

 

X

 

100

         

X

 

100

Mario Resca        

X

 

X

 

81

 

3

         

X

 

100

       
Pierluigi Scibetta        

X

 

X

 

81

 

1

 

X

 

87

 

X

 

100

       
                   
Number of meetings in 2006  

16

     

15

 

9

 

5

     
(1)   Appointments as director or statutory auditor in other listed companies, also outside Italy, in financial, banking, insurance or large companies.
(*)   Appointed by the minority list.
     
The Self-discipline Code foresees the possibility to form, within the Board, a Committee for the proposal of Directors “nomination” especially when cases the Board of Directors notices the difficulty of the shareholders in organizing the prosposal for the appointment, as being in listed companies". The Board of Directors has not formed this Committee in consideration of the shareholding characteristics of Eni.

 

Board of Statutory Auditors
Members      

% attendance
Meetings of the Board of Statutory Auditors

 

% attendance
Meetings of the Board of Directors

 

Number of other
appointments
(1)




 
 
 
Chairman            
Paolo Andrea Colombo  

100

 

94

 

6

Auditors            
Filippo Duodo  

55

 

81

 

1

Edoardo Grisolia  

65

 

63

   
Riccardo Perotta (*)  

95

 

88

 

3

Giorgio Silva (*)  

95

 

100

  2
Number of meetings in 2006  

20

 

16

   
     
(1)   Appointments as director or statutory auditor in other listed company, also outside Italy, or in financial, banking, insurance or large companies.
(*)   Appointed by the minority list.
 
For presenting a list shareholder or group of shareholders must hold at least 1% of voting shares in an ordinary Shareholders' Meeting.

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Other information to be disclosed under the Self-discipline Code (required by to the Self Discipline Code published by Borsa Italiana in 2002)
   

Yes

 

No

   
 
System of delegated powers and transactions with related parties        
The Board of Directors delegated powers defining:        
a) limitations  

X

   
b) exercise  

X

   
c) periodicity of information  

X

   
The Board of Directors reserved examination and approval of relevant transactions (including transactions with related parties)  

X

   
The Board of Directors defined guidelines for identifying relevant transactions  

X

   
Such guidelines are described in the report  

X

   
The Board of Directors defined procedures for examination and approval of transactions with related parties      

X (*)

Such procedures are described in the report      

X (*)

         
Procedures for the latest appointment of Directors and Statutory Auditors        
Lists of candidate directors were deposited at least 10 before the date set for appointment  

X

   
Lists were accompanied by sufficient information on candidates  

X

   
Candidates to the role of director disclosed information that qualified them as independent  

X

   
Lists of candidate auditors were deposited at least 10 before the date set for appointment  

X

   
Lists were accompanied by sufficient information on candidates  

X

   
         
Meetings        
The company approved regulations of meetings  

X

   
The regulations are attached to the report (indication of where to find it online is provided)  

X

   
         
Internal Control        
The company appointed persons responsible for internal control  

X

   
Such persons do not report to managers of operating divisions  

X

   
Internal office responsible of internal control (art. 9.3 of the code)      

Internal Audit

         
Investor relations        
The company appointed an investor relations manager  

X

   
Information on investor relations manager (telephone, address, e-mail) and unit      

Investor Relations (**)

     
(*)   Procedures will be prepared after the pubblication by Consob of the general principles as per Article 2391-bis of the Civil Code introduced by Legislative Decree No. 310 of December 28, 2004.
(**)   Eni SpA - Piazza Vanoni, 1 - San Donato Milanese (Milan) 20097 Italy - Tel. 02 52051651 - Fax 02 52031929.

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Commitment to sustainable development

INTRODUCTION

 

 

 

In keeping with its tradition and leveraging on its track record with the values it consolidated in the course of time and on the skills and passion of the persons working for it, Eni confirmed and renewed its commitment to sustainable development which touches upon various aspects of its activities: from the enhancement of persons to the respect for the environment, to the development of local communities, to technological innovation. These are priorities for all companies, but the more so for a large international company operating in a business where a good management of resources and social and environmental issues is one of the keys for success.
Eni is committed to promoting the sustainability of its results in time and to widening its relations with its stakeholders, improving corporate performance and increasing the value of intangible assets. Eni’s business model will therefore be adjusted in order to guarantee that the goal of sustainability becomes an integral part of its management and development processes.
Assigning value to its experience, in 2006, Eni introduced the issue of sustainability as a tool for management and integrated communication. It therefore started a specific project that was carried out by various organizational units and determined the creation of a unit specifically dedicated to sustainability.
In its meeting of February 22, 2007 Eni’s Board of Directors discussed and approved the strategic guidelines of its 2007-2010 Strategic Plan where it identified the main challenges and commitments in the area of sustainability in the next years.
For the first time this year, Eni’s reporting system includes a Sustainability Report, which will be published along with this Annual Report and is available in the “Sustainability” and “Investor Relations” sections of Eni’s website (www.eni.it).
  Since 2001, in the field of human rights, Eni has been supporting the United Nations’ initiative Global Compact which aims at promoting policies and practices oriented to sustainability by means of the sharing and application of ten basic principles in the fields of human rights, workplace standards, protection of the environment, fight against corruption.


Challenges and commitments
As concerns the various areas impacted by sustainability, Eni identified the main challenges that oil & gas companies will have to face in future years and defined its commitment to the attainment of sustainable development.

Governance and stakeholder engagement
To the greater attention paid to the transparency and sustainability of its governance model and processes Eni responded by committing itself to:
  • set up and strengthen a governance system that corresponds to international best practices, capable of managing complex situations in numerous countries in the world and the challenges of sustainable development;
  • adopt systematic stakeholder engagement forms, extending dialogue on the issues of sustainability and corporate responsibility with relevant stakeholders.

Persons
To the competition in hiring and maintaining qualified professionals and to the need to favor the development of local personnel, at the same time protecting their health and guaranteeing high security standards Eni

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responded by committing itself to:
  • attract the best domestic and international resources;
  • manage human resources internationally with homogenous tools, promoting diversity;
  • promote health and safety of employees, contractors and local communities;
  • enhance the potential and professional capability of its human resources.

Environmental responsibility
To the challenge of meeting the increasing demand for energy while at the same time mitigating emissions and the impact on ecosystems Eni responded by committing itself to:

  • develop preferentially fossil sources with low carbon intensity, in particular natural gas;
  • participate actively in emission trading systems and in projects aimed at reducing emissions based on the flexible mechanisms suggested by the Kyoto Protocol;
  • mitigate the local environmental impact of its activities by improving environmental performance and recovering and reusing resources;
  • reduce its ecological footprint also by means of remediation and reclaiming activities;
  • preserve biodiversity also by means of improved monitoring techniques of onshore and offshore ecosystems.

Innovation
To the strategic importance of innovation for a sustainable use of energy sources Eni responded by committing itself to:

  • develop technologies that increase the availability of hydrocarbons, maximizing the use of existing reserves and protecting safety and the environment in the exploration of new resources;
  • reduce its contribution to climate change by investing in innovation capable of generating discontinuity such as emerging solar technologies;
  • anticipate regulations on fuel quality, the evolution of engines and of market demands, by entering the field of marketing and extending the use of biofuels with high performance and low environmental impact.

Territory and communities
To the need for involvement of local stakeholders and the support of development of local communities Eni responded by committing itself to:

  • promote stakeholder consultation also at the level of local communities, on industrial projects aimed at enhancing the value of local socio-economic systems of the countries and local communities where it operates;
 
  • cooperate with governments and local authorities and with international non-governmental organizations on crucial issues;
  • promote actions for supporting the ability for autonomous development of local communities.

Stakeholder engagement
Eni is aware that the creation of value and its sustainability in time depend on the quality of its relations with its stakeholders. Eni’s strategy includes a serious commitment to the promotion of an open and fruitful dialogue with all the organizations legitimately interested in Eni’s activity as well as a commitment to respect these organizations’ requirements.
This approach is crucial for a large international company that operates in complex environments, where the proper management of stakeholders’ legitimate interests and expectations is a key factor for success.
Eni has adopted a stakeholder engagement methodology (identification, analysis and consultation) which provides its business units with all the elements required to receive feedback from stakeholders thus increasing the level of consensus on projects. In 2006, Eni also prepared a reference and support methodology for the evaluation and management of the social impacts it produces in the areas where it operates by means of a Guide to Social Impact Assessment (SIA).
This guide, prepared on the basis of the most advanced international guidelines contains:

  • references to Eni principles and values;
  • a description of the most relevant socio-economic issues;
  • methods for impact evaluation;
  • operating tools for impact management within projects;
  • a detailed bibliography.

During its preparation the guide has been tested as working document at some operating sites (Kashagan, Karachagansk, Australia, Norway).
More detailed information on the management of stakeholder engagement is found on Eni’s website in the area Sustainability and in the Report on Sustainability.

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HUMAN RESOURCES AND ORGANIZATION

 

 

 

To Eni the persons working in its production system represent a wealth to be safeguarded and enhanced with careful career paths. This path, made up of accurate development and training initiatives customized to roles and persons, along with the respect of shared ethical values, represents a key factor for the creation of sustainable value in the long term. Eni’s main objectives for its human resources are: to guarantee safety and health of all employees and contractors; to plan initiatives for the management and development of human resources, orienting personal development and growth consistently with the evolution of business; to attract the best resources at domestic and international level through intense links with universities and research centers and actively contributing to the training of young generations; to develop and share know-how through the systematization and dissemination of knowledge and the best international corporate practices; to manage human resources internationally with homogenous tools respecting local regulations and cultures; to obtain excellent results in industrial relations at domestic and   international level; to achieve maximum efficacy in internal communication, engagement and training.

More detailed information on the management of human resources is found on Eni’s website in the area Sustainability and in the Report on Sustainability.

Employees and labour costs
At December 31, 2006, Eni’s employees totaled 73,572, with an increase of 1,314 employees from December 31, 2005, or 1.8%, reflecting a 1,741 increase in employees hired and working outside Italy and a decline of 427 employees hired in Italy.
Employees hired in Italy were 39,765 (54% of all Group employees). Of these, 36,881 were working in Italy, 2,697 outside Italy and 187 on board of vessels, with a 427 unit decline from 2005; of these 41 persons left the group due to changes in consolidation.
The process of improvement in the quality mix of employees continued in 2006 with the hiring of 2,208 persons, of which 722 with open-end contracts. A total

 

Employees at year-end  

(units)

  2004   2005   2006   Change   % Ch.
       
 
 
 
 
Exploration & Production   7,477     8,030     8,336     306     3.8  
Gas & Power   12,843     12,324     12,074     (250 )   (2.0 )
Refining & Marketing   9,224     8,894     9,437     543     6.1  
Petrochemical   6,565     6,462     6,025     (437 )   (6.8 )
Engineering & Construction   25,819     28,684     30,902     2,218     7.7  
Other activities   4,983     2,636     2,219     (417 )   (15.8 )
Corporate and financial companies   3,437     5,228     4,579     (649 )   (12.4 )
    70,348     72,258     73,572     1,314     1.8  
   

 

 

 

 

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of 1,486 persons were hired with this type of contract and with apprenticeship contracts, most of them with university qualifications (824 persons of which 532 are engineers) and 632 persons with a high school diploma. During the year 2,599 persons left their job at Eni, of these 1,960 had an open-end contract and 639 a fixed-term contract.
Employees hired and working outside Italy at December 31, 2005 were 33,807 (46% of all Group employees), with a 1,741 persons increase due to the positive balance of new hires with fixed-term contracts and persons leaving their job in Saipem and Snamprogetti (1,853 employees) and the negative balance (112 persons) of persons leaving the job and new hires with open-end contracts in the rest of the Group.
Labor costs increased from euro 3,351 million in 2005 to euro 3,646 million in 2006, a euro 295 million increase, or 8.8%, reflecting primarily redundancy incentives, ordinary payroll dynamics and an increase in average workforce outside Italy in particular in the Engineering & Construction segment, offset in part by a decrease in average workforce in Italy.

Organization
Eni introduced significant actions for the upgrading of structures and processes to the new integrated corporate model adopted which includes: a full assumption of responsibility of businesses and their integration on wide reaching actions, the strengthening of Eni Corporate’s role of orientation and coordination, the sharing of business services with the aim of greater efficiency of services provided, the integrated control and governance of performance by means of heads of professional units, a widespread simplification of the

  organizational set-up of companies, full compliance of control processes and systems with laws and regulations.

Management and development
of human resources
Eni started and completed various initiatives aimed at making the evaluation and development of human resources more efficient. In particular, Eni completed a plan of rejuvenation of management which determined a significant decrease in average age at all levels of management and enhanced the tools for the evaluation of the development potential of resources, coupling the appraisals made at (hierarchical and functional) line level with those performed by external experts. These activities were addressed to key managers, developing young managers and newly recruited graduates. Eni performed an updating of policies directed to employees outside Italy and introduced compensation schemes adequate with the dynamics of international resource markets. The whole body of internal regulations and methodologies for planning, managing and developing human resources is currently under review, also in light of the increasing importance of sustainability.
With nearly 46% of its employees of non-Italian nationality, Eni has always considered diversity as an element that generates value and the ability in managing it as a key factor for success. In the countries where it operates, Eni promotes the development of skills of local human resources and the construction of a shared culture by means of training initiatives oriented to the understanding of intercultural diversity, intercultural communication and multicultural teamwork, initiatives that have been performed also within the European Works Council with the active participation of workers’ unions.

Training
Eni considers training one of the strong points of the management of human resources.
The number of hours dedicated to training and the number of employees participating in training initiatives are evidence of Eni’s significant commitment in Italy and outside Italy.
In 2006, expenditure for training amounted to euro 22.6 million (up about 2% from 2005).
In 2006, a total of 1,167,633 training hours (1% lower than in 2005) were provided in Italy to a total of 23,941 employees (232 senior managers, 6,822 middle managers and senior staff, 12,180 employees and 6,192 workers) for a total of 90,319 participations.

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In 2006, expenditure for training outside Italy amounted to euro 34.6 million. A total of 1,131,530 training hours (2% higher than in 2005) were provided to a total of 8,091 employees (208 senior managers, 2,604 middle managers and senior staff, 3,585 employees and 1,694 workers) for a total of 28,487 participations.
Eni Corporate University, in its role of group company covering the fields of personnel selection, training and knowledge management aimed at matching the quality of Eni’s human resources with the company’s strategies, covering the whole “knowledge cycle” from the planning of requirements to the construction of integrated academic curricula in cooperation with universities in Italy, up to the selection of new talents and their training during their professional lives. In 2006, ECU prepared a thorough survey of the issue of knowledge management in Eni’s business units and prepared a “Plan for the development of Eni’s knowledge system 2007-2008”.
In early 2007, Eni celebrated the 50th anniversary of the establishment of the Scuola Mattei operating in research and post-graduate training. The integration of energy and the environment and an international faculty and students are the key features of the school. From its foundation in 1957, the school trained nearly 2,500 young talents, of these 55% came from nearly 100 countries of the world. It recently created three new curricula directed to about 100 students from Italy and the rest of the world.

Industrial relations
Industrial relations within a consolidated and structured system represented an efficient and consistent support to Eni’s strategic choices and to the completion of reorganization processes underway. With Italian workers’ unions, Eni defined the renewal of collective contracts (for the segments of energy and oil and chemicals) expired in late 2005. As for the collective contract for the gas-water segment, also expired at the end of 2005, negotiations between workers’ unions and companies’ organizations are underway.
Internationally, Eni continued its dialogue with workers’ unions in specific forums such as the European Works Council. Eni’s Multicultural Training Project, which takes place every year in a different country with the cooperation of members of the EWC, held training courses in France addressed to 300 employees of Saipem SA. This course was awarded the first prize Etica&Impresa at the end of 2006.
  Health
Activities for the protection of health aim at improving general work conditions and are developed according to three main principles:
  • protection of employees’ health;
  • prevention of accidents and professional diseases;
  • promotion of healthier behaviors and life styles in workplaces.

Eni has a network of 307 own health care centers located in its main operating areas of these 217 centers are outside Italy and are managed by expatriate and local staff (415 doctors and 442 paramedics). A set of international agreements with the best local and international health centers guarantees efficient service and timely reactions to emergencies.
In 2006, Eni boosted its E-medicine program aimed at increasing the quality of health care provided to employees and to health operators within and outside Italy, that integrates computerized technologies and advanced telecommunication systems.
Eni started a program of prevention for its employees, both through information campaigns and by means of screening procedures and direct actions accessed on a voluntary basis. In the area of prevention of infective diseases, Eni continued its campaign for vaccination against flu that is widely followed by employees.
Outside Italy, Eni promoted specific information campaigns for the protection of its employees, their families and local communities, such as those for the prevention of malaria (in Nigeria) and the prevention of HIV transmission (in Nigeria and Congo).
For employees hired in Italy and working outside Italy, Eni has a specific program that includes training on the specific health risks they might encounter in each country and information on how to cope with them.
Eni also entered an agreement with International SOS that provides qualified health services throughout the world, as well as repatriation in case of serious emergency situations.

Safety
Eni has always been deeply engaged in the issue of the safety of its workers, of the people living in the areas where its industrial sites are located and of its producing assets. Its strategy has been based on:

  • the dissemination of a safety culture within its organization;
  • a common policy, specific guidelines for proper management systems meeting international standards;

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  • control, prevention and protection from exposure to dangerous situations;
  • minimization of exposure to risk in all production activities.

Eni’s Guide on the evaluation and mitigation of risks published in 2004 by the HSE department describes the methods applied in the identification of dangers, evaluation and mitigation of risks associated to plants, processes, transportation means, workplaces, chemical substances and products used, produced and marketed.
This process includes the following phases:

  • identification of all exposures and risks related to processes, products and operations performed;
  • evaluation of risks in terms of seriousness and frequency of accidents;
 
  • investigation and analysis of accidents in order to learn from them and increase the ability to prevent and mitigate risks;
  • development of action plans for the minimization of risks focused mainly on capital expenditure, implementation of safety management systems and training of staff;
  • monitoring and appraisal based on the identification, evaluation, correction of individual and process performance.

In 2006, safety indicators improved from 2005. The injury frequency rate was 3.07, down 3%, and the injury severity rate was 0.09, down 10% from 2005.

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RESPONSIBILITY TOWARDS THE ENVIRONMENT

 

 

 

Reference scenario
The attention currently paid to the relevant issues of environmental sustainability and the corresponding regulatory developments at international level stimulate companies to engage beyond the simple compliance both as concerns locally and globally critical situations.
The precautionary principle that informs current regulations requires that the actions taken by industrial companies to reduce their environmental footprint privilege the preventive approach to the remediation of damage done.
In addition, the current operating context is characterized by increasing avoidance of risks thus posing stricter constraints to the “freedom of operations”, due to the progressive internalization of environmental externalities and also for the growing participation of local stakeholders to decision making processes. Companies are therefore required to
  be more transparent on their environmental performance, as they are subject to careful scrutiny by stakeholders. In all its activities, Eni is actively committed to reducing its environmental footprint, decreasing its energy and water consumption, reducing local pollution of air, water and soils as well as waste production and to reclaiming discontinued industrial sites. Special attention is paid to the protection of biodiversity.
More detailed information on the reduction of the environmental footprint is found on Eni’s website in the area Sustainability and in the Report on Sustainability.

Rational use of natural resources
The management of natural resources is aimed at a rational and sustainable use of these resources and their protection in all Eni’s operations.

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The application of the best available technologies for the control of emissions into the atmosphere is one of the pillars of the current environmental regulations (IPPC/AIA, Italian environmental Law No. 152/06) and finds a responsible partner in Eni that strives to reduce the impact of its production processes on the environment.
In this light, Eni approved capital expenditure for the technological improvement of the treatment of waste fluids, combustion in gas turbines and devices for the reduction of effluents applicable in combined cycle plants for the production of electricity, the control and monitoring of emissions from plant components and transport of fuels.
The implementation directives for the management of waters concern the reduction in pure water consumption by developing recycling opportunities and the minimization of water discharge that in many instances is obtained at levels higher than those required by applicable laws.
Eni made capital expenditure aimed at the adoption of integrated production cycles with a limited and combined use of water, at the construction of water treatment plants with the most updated technologies and at the construction of monitoring systems capable of providing periodic control of the most significant parameters.
The protection of soils and ground waters is a very relevant aspect for the environment. Great attention is paid to it at the organizational and economic level. For years, Eni has been carrying out numerous programs for the protection of soils and the reclamation of soils and ground waters. Eni’s business units are provided with an internal organization that takes care of management and technical aspects, making recourse to highly qualified external professionals to carry on their reclaiming activities.
Eni is also active in the area of waste produced by its industrial units with the aim of reducing its generation
  and improving its final destination by increasing recycling and recovery and reducing incineration and landfilling.

Oil Spill
Production, handling and transport of oil products can give rise to spills of variable size. In order to protect the areas where it operates, Eni defined responsibilities and operating modes aimed at reducing the negative impact of oil spills. Tools available include the recourse to external professionals and/or international organizations.
In 2006, a total of 139 oil spills were registered for a total of 6,150 bbl of oil spilled.

Biodiversity
Eni considers biodiversity an integral element of sustainable development and is engaged in the impact evaluation of its exploration and production activities both onshore and offshore. This engagement takes the form of supporting conservation projects on land and in the sea and of organizing actions that raise attention for biodiversity. The most relevant current projects are addressed to:
  • Val d’Agri, an ecologically sensitive area rich in animal and vegetable species as confirmed by EU protected sites found in the valley;
  • Ecuador, a country provided with ecosystems with an inestimable value, such as tropical forests containing rare species at risk;
  • the Mediterranean Sea, where a project is evaluating the ecosystemic impact of platforms;
  • the Arctic Sea, where the ecosystem is considered extremely valuable and fragile due to the lack of antropization;
  • Kazakhstan, where Eni is currently organizing a workshop on biodiversity focusing on the Caspian Sea, a natural reserve characterized by many rare species.

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THE FUTURE OF ENERGY AND INNOVATION

 

 

 

The future of energy
The global energy scenario is complex and worries are widespread regarding the future of energy. The debate on the constant increase in energy consumption and the dreaded exhaustion of oil reserves often masked the real criticalities of the current energy system (insufficient capital expenditure in the Nineties, crisis due to overproduction, bottlenecks and inadequacy of refining systems, waste and inefficiency in energy use in industrial countries). Despite these events, hydrocarbons will continue to dominate the energy scenario in the next decades and to represent the most important and strategic energy source. Eni, a company active in oil and gas, will continue to deploy its activities in order to meet energy requirements.
At the current state of knowledge, Eni believes that the massive use of fossil fuels can contribute to climate change and is therefore actively engaged in favor of a responsible use of energy and the protection of the environment. Eni’s growth model is sustainable development, and in particular, Eni is committed to mitigating the effects of climate change due to greenhouse gas emissions.

New partnership models and access to oil reserves
Partnerships with producing countries, infrastructure and innovation will play a basic role in guaranteeing the security of supplies, which is the main criticality of the world energy system. In fact, at the current state of knowledge, total recoverable hydrocarbon reserves amount to approximately 5,000 billion barrels and will allow to meet energy requirements for over 100 years. International oil companies such as Eni, however, have
  access to less than 20% of proved hydrocarbon reserves, which are mainly controlled by national oil companies. IOC’s resources available for capital expenditure are limited and represent new economic and technological challenges in particular in the new frontiers of conventional hydrocarbons (e.g., production from fields in ultra deep waters) and non conventional hydrocarbons (such as the extraction of hydrocarbons from tar sands and extra heavy oils). Eni is engaged in maintaining high rates of production growth while guaranteeing the sustainability of its business in the medium- to long-term through the integral replacement of reserves produced. Eni’s activities are oriented to the exploration of basins located in Africa, the Barents Sea, the Middle East and the Gulf of Mexico and to the development of fields with extended productive life in West Africa, North Africa and Kazakhstan.
The evaluation of new expansion opportunities in the field of non conventional oils and the goal of increasing the reserve replacement ratio are pursued by increasing activities and capital expenditure in R&D and innovation and paying great attention to the impact of such projects on the environment and local communities.
In this context, Eni is constantly engaged in improving its models of cooperation with producing countries in order to overcome the current criticalities of the global energy system. Eni’s strategy of cooperation with producing countries will be characterized by a dialogue with partners. Eni is ready to promote new strategic alliances with producing countries based on the joint development of integrated projects aimed at reaching

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the targets of energy and economic development set by each country. This perspective translates into a renewed commitment to develop innovative and fair partnerships and cooperation modes.
In this light, Eni and the Russian company Gazprom entered into a significant strategic agreement in 2006 that will provide Italy with a relevant share of its natural gas requirements until 2035. A description of the main features of this agreement and its impact on Italy’s energy requirement is found in the Operating Review - Gas & Power and on Eni’s website in the area Sustainability.

Actions for mitigating the risks of climate change
The issues of energy safety and climate change, with the related greenhouse gas emissions, are the central issues of the development of energy systems. Eni defined and adopted a carbon management strategy with the following goals:
  • preferably develop fossil fuels with low carbon intensity, in particular natural gas;
  • pursue gas-electricity integration exploiting the high efficiency of combined cycles and co-generation;
  • actively participate in the emission trading system, promoting the reduction of emissions in its industrial plants;
  • participate in projects based on CDM (Clean Development Mechanisms) and JI (Joint Implementation) foreseen by the Kyoto protocol;
  • progressively reduce gas flaring and gas venting associated to oil production creating the conditions for selling that gas on local and international markets;

 
  • develop technologies for the separation and the geologic confinement of CO2;
  • design and promote a sustainable energy system based on a wide array of sources and high efficiency techniques.

Along these guidelines Eni achieved results that mark it as a low (direct and indirect) CO2 emission company.
As concerns emission trading, Eni is one of the largest Italian and European operators. In Italy, it is the first company for industrial plants involved (60 plants, of these 58 in Italy).
In order to participate to emission trading schemes, Eni developed a series of coordinated activities and an extensive management organization, that starts from each industrial plant, ascends to business units and is consolidated at corporate level. This organization passed its first test phase successfully in the first months of 2006, when emissions for 2005 were verified and trading took place.
In addition to participating to European emission trading schemes, Eni is also developing a portfolio of projects for emission reduction based on flexible mechanisms under the Kyoto Protocol.
In November 2006, the electricity generation project in Okpai in Nigeria was registered as CDM, as it uses associated gas, formerly flared. A first goal achieved in the reduction of emissions related to gas flaring and venting.
Eni’s longer term strategy envisages the development of fuels with lower environmental impact and more efficient technologies for the production of hydrogen, the design and promotion of a sustainable energy system based on a wide array of sources and high efficiency techniques.

Development of natural gas
Consumption of natural gas has been increasing faster than consumption of oil. The growing use of natural gas is also an efficient response to the risk of climate change. Its high environmental sustainability, its abundance and the new transport technologies show that natural gas is the energy source with the highest growth potential of the next decades. Natural gas, in fact, is more efficient and less polluting that coal and will be increasingly used in main markets (in particular the United States and Europe) for power generation.
Eni is engaged in developing activities and upgrading transport infrastructure in the natural gas segment, with the strategic objective of strengthening its leadership in Europe by maximizing the value of its portfolio of equity gas in Italy, Libya, Egypt and the

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North Sea and of its long term supply contracts with large producers such as Gazprom, Sonatrach, Gasunie and Statoil.
In the area of natural gas development, in addition to the mentioned agreement with Gazprom, Eni also entered an agreement for the expansion of the Damietta liquefaction plant in Egypt and signed a shareholders’ agreement for the construction of a liquefaction terminal at Brass, Nigeria. These agreements are especially relevant keeping into account Eni’s interest for developing liquefied natural gas and set the premises for an optimal use of new fields in Egypt and for Eni’s natural gas reserves in Nigeria.

Innovation
Technological innovation represents a cornerstone of Eni’s strategies. All the great strategic challenges of the next years and decades require imagination and creativity: from the environmental and climate emergencies to the more and more difficult access to hydrocarbon reserves large, but mainly controlled by producing countries; from the identification of relevant discontinuities in the production of energy from renewable sources to the optimization of production processes up to the solution of problems existing in countries where Eni has been present for a long time or where it recently entered.
In order to attain these goals in 2006 Eni has deeply revised the organization of its R&D activities. On August 1, 2006 EniTecnologie was merged into Eni. The resources dedicated to research have been assigned to the various divisions according to the existing knowledge and current projects. Divisions have become directly responsible for R&D activities of up-mid-downstream oil and gas (including the environmental ones affecting their segments) and of their budgeting. At the same time the Strategies and Development Department of of Eni Corporate has been entrusted with the task of defining strategic guidelines for technological innovation at group level, of playing a controlling and monitoring role on projects and activities and of developing research in the field of new energy technologies. This department also directly manages the “Along with petroleum” program, aimed at identifying and developing research projects on the most advanced aspects of renewable energy sources and energy efficiency.
In its meeting of November 23, 2006, Eni’s Board of Directors discussed and approved the strategic
  guidelines included in the R&D Master Plan which identifies the main challenges that the energy sector will have to face in future years, the strategic priorities and the innovation objectives to support them.
In 2006, Eni invested euro 222 million in research and development (euro 204 million in 2005), of these 39% were directed to the Exploration & Production segment, 32% to the Refining & Marketing segment, 22% to the Petrochemical segment and 7% to the Engineering & Construction segment.
At December 31, 2006, a total of 1,160 persons were employed in research and development activities.
In 2006 a total of 39 applications for patents were filed (26 in 2005).
Among the initiatives undertaken, projects have been started in the area of production and marketing of new generation biofuels to be sold on the market in a few years.
More detailed information on innovation is found on Eni’s website (www.eni.it) in the area Activities and Strategies and in the Report on Sustainability.


Main initiatives in innovation in 2006

E&P Division
Numeric and High Resolution Geophysical Prospecting Techniques
The development of the simulator of oil systems “Steam 3D” has been completed. It allows to describe the evolution of complex geological structures in time. The first applications on the field allow to reduce exploration risk and to improve the geo-mechanical description of the field.
Development continued of the proprietary CRS technology (3D Common Reflection Surface Stack) that aims at allowing prospecting in areas characterized by low seismic response.

Advanced Drilling Systems and Well Testing
The Geosteering project developed by Eni in joint venture with Shell aims at the development of technologies capable of providing geological information on not yet drilled strata (around the scalpel up to the surface) while drilling. In the first six months of 2006, various downhole prototypes have been prepared and in the second half of the year the technology was tested in the well. Testing will continue until the first half of 2007.

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Sulphur management
In 2006, the integrated research program Sulphur and H2S management in E&P operations related to the treatment of natural gas with high H2S content has been completed. An innovative proprietary system called Concrete Wall has been developed for the massive storage of sulphur and H2S bulk removal. In 2007 demonstration units for the treatment and storage of sulphur will be developed along with the study the behavior of materials in very sour environments and under extreme pressure and temperature conditions.

Gas to liquids project (GTL)
In 2006, with the cooperation of IFP/Axens, Eni completed the technology handbook for this proprietary technology for the conversion of gas to liquids via Fischer-Tropsch synthesis and the plan for a 37 kbbl/d industrial unit.

Conversion of heavy crudes and fractions into light products
(in cooperation with the R&M Division)
Testing continued at the Taranto demonstration plant of Eni’s proprietary technology EST, a process of catalytic hydroconversion in the slurry phase of non conventional crudes, extra heavy crudes and refining residues that allows to convert asphaltenes (the hard fraction of heavy crudes) totally into naphtha, kerosene, diesel fuel. In 2007 Eni plans to complete the collection of information for designing and building its first industrial plant.

SCT-CPO Project (Short Contact Time - Partial Catalytic Oxidation)
(in cooperation with the R&M Division)
At the Milazzo research center, SCT-CPO (partial catalytic oxidation with short contact time of liquid and gaseous hydrocarbons) technology has been validated on the pilot scale for producing hydrogen at competitive costs, also in medium to small sized plants with higher flexibility as compared to refinery feedstocks. In 2007, Eni plans to complete the collection of information for designing and building its first industrial plant.

GHG Project (Green House Gases)
(in cooperation with the R&M Division)
Work continued on the integrated Green House Gases research program, aimed at verifying the industrial feasibility of the geological sequestration of CO2 in depleted fields and salty aquifers. The technical
  feasibility study of the geological sequestration of CO2 has been completed and in 2007, Eni expects to start testing in the field.

G&P Division
Natural gas high pressure transport (TAP)
The TAP project will contribute to developing the
most advanced long distance, high capacity, high pressure and high grade solutions with relevant
targets related to:
  • transport on distances over 3,000 kilometers;
  • natural gas volumes to be transported of about 20-30 billion cubic meters/year;
  • pressure equal to or higher than 15 MPa;
  • use of high and very high grade steel.

The TAP technology is expected to allow a decrease in the consumption of natural gas used in compressor stations.
In 2006, testing continued on two infrastructure (one integrated in the system of Snam Rete Gas), the first technology handbook version was published and a hypothetical 3,400 kilometer long gasline in X100 steel in Central Asia was designed.

R&M Division
Reformulation of fuels and lubricants
Eni continued to improve its “Blu” fuels (BluDiesel and BluSuper).
It also started a new phase of its clean diesel fuel program that aims at identifying the optimal formula for a diesel fuel with high performance and low particulate emissions using as benchmark GTL Fischer-Tropsch gasoil (obtained from the conversion of natural gas into liquids - GTL project). Research will be applied also to the identification of refining schemes for obtaining this product.

Other projects

  • Green Diesel - the project aims at the production of biodiesel in refineries by means of a new hydrocracking process for vegetable oils developed in cooperation with an international partner;
  • Ensolvex - aimed at the further industrial application of the process for the reclaiming of soils polluted by organic substances;
  • EWMS (Early Warning Monitoring System) - in-field application of the outcome of research on remote monitoring and advanced control.

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Polimeri Europa
An ABS plant was modified in order to allow the production of new ABS (acrylonitryle-butadiene-styrene) polymers for the segment of injection moulding and also to increase ABS production capacity for the extrusion area.
A plant has been modified to increase production capacity of high impact resistance polystyrene and a new range of products in this area is being consolidated.
A new type of expandable polystyrene with very low pentane content has been produced.
Test production has been started of new innovative kinds of polybutadiene and styrene butadiene copolymer for the tyre segment, that is expected to be industrialized.
Two new grade of styrene isoprene copolymers have been consolidated at industrial level for the segment of hot melt adhesives.
Two new grades of styrene butadiene copolymers have been tested in an industrial plant for the compounding application in the segment of hot melt adhesives.
The first industrial testing of an ethylene propylene copolymer has been successful.
New co-polymers of ethylene have been produced by means catalytic Ziegler/Natta system for injection moulding and for the following specialist application segments: bioriented films, high performance film cast and medium density lamination.

Corporate
In addition to the preparation of the R&D Master Plan, corporate activities were focused on the definition of research projects in the field of solar energy conversion and manufacture of new generation biofuels, that are due to start in 2007.


Territory and Communities
Eni operates in over 70 countries respecting the human rights of populations, their territory and the environment, contributing to improving the quality of life and the socio-economic development of the communities where it is present. This commitment is the basis of corporate behaviors based on the respect for

  ethnic, social or cultural diversity of the various communities with which Eni interacts.
The search for integration with varied social and cultural situations is part of Eni’s tradition. In order to favor a proper integration Eni:
  • cooperates with national and local authorities and with international NGOs;
  • sponsors initiatives that will proceed autonomously in the social, cultural and environmental fabric of the different communities;
  • promotes dialogue with local communities on the industrial options by means of tools for active participation;
  • favors the improvement of the socio-economic systems where it operates using wherever possible local goods and services, consistently with its industrial requirements, in order to maximize local content;
  • extends the initiatives for its personnel to their families and to local communities where it operates, in particular as concerns health.

Eni’s main interventions for the protection and development of local communities concern:

  • Italy: activities included in the intent protocol signed with the Basilicata Region for the Val d’Agri for an overall expenditure of approximately euro 160 million in the 1999-2019 period;
  • Karachaganak: infrastructure projects requested by the local authorities for an overall expenditure of approximately euro 9 million, paid by the Consortium;
  • Caspian Sea: infrastructure projects requested by the local authorities for an overall expenditure of approximately euro 309 million, paid by the Consortium;
  • Libya: recruiting, training, health assistance, archaeology, industrial development, as provided for by the masterplan for an overall expenditure of approximately euro 110 million for a period of eight years.
    Aware of its role of member of a social community, in 2006 Eni established Eni Foundation, an entity that autonomously promotes and carries out social initiatives with specific attention to childhood and old age in Italy and abroad.

More detailed information on such initiatives is found on Eni’s website in the section Sustainability and in the Report on Sustainability.

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RISK MANAGEMENT

 

 

 

Foreword
The main risks identified and managed by Eni are the following: (i) market risks deriving from the exposure to the fluctuations of interest rates, of exchange rates between the euro and the US dollar and the other currencies used by the company, as well as the volatility of commodity prices; (ii) the credit risk deriving from the possible default of a counterparty; (iii) the liquidity risk deriving from the risk that suitable sources of funding for the Group’s business activities may not be available; (iv) the operation risk deriving from the occurrence of accidents, malfunctioning, failures with damage to persons and the environment affecting operating and financial results; (v) the country risk in oil & gas activities.

Market risk
Market risk is the possibility that changes in currency exchange rates, interest rates or oil, natural gas and power prices will adversely affect the value of the group’s financial assets, liabilities or expected future cash flows. Their management follows a set of guidelines and procedures based on a framework envisaging centralization of the treasury function in two captive finance companies operating in the Italian and international financial markets. In particular, the finance company operating on the domestic market (Enifin) manages all the transactions concerning currencies and derivative financial contracts. The commodity risk is managed by each business unit while Enifin manages the negotiation of hedging derivatives. Starting on January 1, 2007, this task is being performed by Eni SpA following the incorporation of Enifin.
In order to minimize market risks related to changes

  in interest rates and exchange rates and to manage exposure to commodity prices fluctuations, Eni enters into various transactions using derivative financial instruments (derivatives). Derivatives are contracts whose value is derived from one or more underlying financial instruments, indices or prices that are defined in the contract. The group also trades derivatives in conjunction with these risk management activities. Eni does not enter into derivative transactions on a speculative basis.

The framework defined by Eni’s guidelines prescribes that measurement and control of market risk are to be performed on the basis of maximum acceptable levels of risk exposure defined in accordance with value-at-risk techniques. These techniques make a statistical assessment of the market risk, i.e., potential gain or loss in fair values.
Eni’s guidelines prescribe that Eni’s subsidiaries use such market risk exposure policies as to minimize market risk. Tolerable market risk exposure is set at the Group level within the central finance department which pools all risk positions of the Group. Calculation and measurement techniques followed by Eni in accordance with established banking standards (such standards are established by the Basel Committee). However, the tolerable level of risk adopted by Eni is more conservative than the recommended one.
Eni’s guidelines prescribe that the exposure to risk from fluctuations in commodity prices is to be managed in a way as to support the effectiveness of operations and to pursue set objectives of industrial margins. Risk exposure within trading activities is defined within maximum levels of value-at-risk attributed at each

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business unit, with the central function managing hedging request. Strategic risk exposure is monitored in terms of value-at-risk, albeit not being hedged in a systematic way.

Exchange rate risk
Exchange rate risk derives from the fact that Eni’s operations are conducted in currencies other than the euro (in particular the US dollar) and by the time lag existing between the recording of costs and revenues denominated in currencies other than the functional currency and the actual time of the relevant monetary transaction (transaction exchange rate risk). Generally speaking, an appreciation of the US dollar versus the euro has a positive impact on Eni’s results of operations, and vice-versa. Effective management of exchange rate risk is performed at the Group level, within the central finance department which matches opposite positions of the Group operating subsidiaries and hedges net positions using derivatives (such as currency swaps, forwards and options). Such derivatives are recognized at fair value on the basis of market prices provided by specialized sources. Value-at-risk deriving from currency exposure is measured daily on the basis of a variance/covariance model, with a 99% confidence level and a 20-day holding period. The transaction currency risk on certain strategic holdings is deemed to be immaterial.

Interest rate risk
Variations in interest rates affect the market value of financial assets and liabilities of the company and the level of finance charges. Eni uses interest rate derivatives such interest rate swaps and interest cross currency swaps to effectively manage the balance between fixed and floating rate debt. Such derivatives are recognized at fair value on the basis of market prices provided from specialized sources. Value-at-risk deriving from interest rate exposure is measured daily on the basis of a variance/covariance model, with a 99% confidence level and a 20-day holding period.

Commodity risk
Eni’s results of operations are affected by changes in the prices of commodities. A decrease in oil, gas and products prices generally has a negative impact on Eni’s results of operations and vice-versa. In order to hedge commodity risk, Eni uses derivatives traded on the organized markets of ICE and NYMEX (futures and options) and derivatives traded over-the-counter (swaps, forwards and contracts for differences, with the

  underlying commodities being crude oil, refined products or electricity. Such derivatives are recognized at fair value on the basis of market prices provided from specialized sources or absent market prices, on the basis of estimates provided by brokers or suitable evaluation techniques. Value-at-risk deriving from commodity exposure is measured daily on the basis of a historical simulation technique, with a 99% confidence level and a one-day holding period.

Credit risk
Credit risk is the potential exposure of the Group to loss in the event of non-performance by a counterparty. The credit risk arising from the Group’s normal commercial operations is controlled by individual operating units within Group-approved guidelines. The monitoring activity of credit risk exposure is performed at the Group level according to set guidelines and measurement techniques. In particular, credit risk exposure to large clients and multi-business clients is monitored at the Group level on the basis of score cards quantifying risk levels. Eni’s guidelines define the characteristics of persons eligible to be counterparty of Eni in derivative contracts and cash management transactions. Eni constantly updates a list of eligible persons which includes highly credit-rated institutions. Eni has not experienced material non-performance by any counterparty. As of December 31, 2005 and December 31, 2006, Eni has no significant concentrations at credit risk.

Liquidity risk
Liquidity risk is the risk that suitable sources of funding for the group’s business activities may not be available. The group has long-term debt ratings of AA and Aa2, assigned respectively by Standard & Poor’s and Moody’s. The group has access to a wide range of funding at competitive rates through the capital markets and banks. It coordinates relationships with banks, borrowing requirements, foreign exchange requirements and cash management centrally.
At present, the Group believes it has access to sufficient funding and has also both committed and uncommitted borrowing facilities to meet currently foreseeable borrowing requirements.
Effective management of the liquidity risk has the objective of ensuring the availability of adequate funding to meet short term requirements and due obligations and also the objective of ensuring a sufficient level of flexibility in order to fund the development plans of the Group businesses. This implies the adoption of a strategy for pursuing

 

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an adequate structure of borrowing facilities (particularly the availability of committed borrowings facilities) and the maintenance of cash reserves.

Country risk
Substantial portions of Eni’s hydrocarbons reserves are located in countries outside the EU and North America, certain of which may be politically or economically less stable than EU or North American countries. At December 31, 2006, approximately 70% of Eni’s proved hydrocarbons reserves were located in such countries. Similarly, a substantial portion of Eni’s natural gas supplies comes from countries outside the EU and North America. In 2006, approximately 60% of Eni’s domestic supply of natural gas came from such countries. Negative developments in the economic and political framework of these countries can compromise temporarily or permanently Eni’s ability to operate economically and to have access to oil and natural gas reserves.
Eni monitors constantly the political, social and economic risk of the approximately 60 countries where it invested or intends to invest with special attention to the evaluation of upstream investments. Country risks are mitigated by means of appropriate guidelines for risk management that Eni defined in its procedure for project risk assessment and management.

Operation risk
The broad scope of Eni’s activities involves a wide range of operational risks such as those of explosion, fire or leakage of toxic products, production of non biodegradable waste. All these events could possibly damage or even destroy plants, facilities, equipment and other property, cause injury or even death to persons or cause environmental damage.
Eni adopted the most stringent guidelines for the

  evaluation and management of health, safety and environmental (HSE) risks, with the objective of protecting Eni’s employees, contractors and clients the populations involved in its activity and the environment and being in compliance with local and international rules and regulations. Eni’s guidelines prescribe the adoption of international best practices in setting internal principles, standards and solutions. An ongoing process for identifying, evaluating and managing HSE risks is at the hearth of HSE operations in each phase of the business activity and is performed through the adoption of procedures tailored on the peculiarities of each business and industrial site.
HSE risks are effectively managed through an integrated management system designed along the principles set in Eni’s Model of HSE operations. This is a general procedure to be applied in all operating sites, based on an annual cycle of planning, implementation, control, review of results and definition of new objectives. The model is directed towards the prevention of risks, the systematic monitoring and control of HSE performance in a continuous improvement cycle, also subject to audits by internal and independent experts. Any environmental emergency is managed by business units locally with their own organization under preset reaction plans to foreseeable events aimed at limiting damage and at activating adequate responses.
Eni has two emergency rooms (in Milan and Rome) provided with real-time monitoring systems for the collection of data on georeferenced maps for all Eni sites and logistics worldwide. Meteorologic equipment is in place to assess dimension, temporal development and other consequences of certain catastrophic events and to enable a real-time planning of first-aid interventions to help mitigate consequences. In addition to its own emergency teams, Eni entered international agreements in order to maximize its ability to react in all its operating sites.

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Glossary
The glossary of oil and gas terms is available on Eni’s web page at the address www.eni.it. Below is a selection of the most frequently used terms.

FINANCIAL TERMS

Dividend Yield Measures the return on a share based on dividends for the year. Calculated as the ratio of dividends per share of the year and the average reference price of shares in the last month of the year.

Leverage Is a measure of a company’s debt, calculated as the ratio between net financial debt and shareholders’ equity, including minority interests.

ROACE Return On Average Capital Employed is the return on average capital invested, calculated as the ratio between net income before minority interests, plus net financial charges on net financial debt, less the related tax effect and net average capital employed.

TSR Total Shareholder Return measures the total return of a share calculated on a yearly basis, keeping account of changes in prices (beginning and end of year) and dividends distributed and reinvested at the ex-dividend date.

OIL AND NATURAL GAS ACTIVITIES

Average reserve life index Ratio between the amount of reserves at the end of the year and total production for the year.

Barrel Volume unit corresponding to 159 liters. A barrel of oil corresponds to about 0.137 metric tons.

Boe (Barrel of Oil Equivalent) Is used as a standard unit measure for oil and natural gas. The latter is converted from standard cubic meters into barrels of oil equivalent using a coefficient equal to 0.00615.

Concession contracts Contracts currently applied mainly in Western countries regulating relationships between States and oil companies with regards to hydrocarbon exploration and production. The company holding the mining concession has an exclusive on mining activities and for this reason it acquires a right on hydrocarbons

  extracted, against the payment of royalties to the State on production and taxes on oil revenues.

Condensates These are light hydrocarbons produced along with gas, that condense to a liquid state at normal temperature and pressure for surface production facilities.

Deep waters Waters deeper than 200 meters.

Development Drilling and other post-exploration activities aimed at the production of oil and gas.

Elastomers (or Rubber) Polymers, either natural or synthetic, which, unlike plastic, when stress is applied, return to their original shape, to a certain degree, once the stress ceases to be applied. The main synthetic elastomers are polybutadiene (BR), styrene-butadiene rubbers (SBR), ethylene-propylene rubbers (EPR), thermoplastic rubbers (TPR) and nitrylic rubbers (NBR).

Enhanced recovery Techniques used to increase or stretch over time the production of wells.

EPC (Engineering, Procurement, Construction) A contract typical of onshore construction of large plants in which the contractor supplies engineering, procurement and construction of the plant. The contract is defined “turnkey” when the plant is supplied for start-up.

EPIC (Engineering, Procurement, Installation, Commissioning) A contract typical of offshore construction of complex projects (such as the installation of production platforms or FPSO systems) in which the global or main contractor, usually a company or a consortium of companies, supplies engineering, procurement, construction of plant and infrastructure, transport to the site and all preparatory activities for the start-up of plants.

Exploration Oil and natural gas exploration that includes land surveys, geological and geophysical studies, seismic data gathering and analysis, and well drilling.

FPSO vessel Floating, Production, Storage and Offloading system made up of a large capacity oil tanker including a large hydrocarbon treatment plant. This system, moored at the bow in order to maintain a geostationary position, is in fact a temporary fixed platform linking by means of risers

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from the seabed the underwater wellheads to the treatment, storage and offloading systems onboard.

Infilling wells Infilling wells are wells drilled in a producing area in order to improve the recovery of hydrocarbons from the field and to maintain and/or increase production levels.

LNG Liquefied Natural Gas obtained through the cooling of natural gas to minus 160 °C at normal pressure. The gas is liquefied to allow transportation from the place of extraction to the sites at which it is transformed and consumed. One ton of LNG corresponds to 1,400 cubic meters of gas.

LPG Liquefied Petroleum Gas, a mix of light petroleum fractions, gaseous at normal pressure and easily liquefied at room temperature through limited compression.

Mineral Potential (“Potentially recoverable hydrocarbon volumes”) Estimated recoverable volumes which cannot be defined as reserves due to a number of reasons, such as the temporary lack of viable markets, a possible commercial recovery dependent on the development of new technologies, or for their location in accumulations yet to be developed or where evaluation of known accumulations is still at an early stage.

Mineral Storage Volumes of natural gas required for allowing optimal operation of natural gas fields in Italy for technical and economic reasons.

Modulation Storage Volumes of natural gas required for meeting hourly, daily and seasonal swings of demand.

Natural gas liquids Liquid or liquefied hydrocarbons recovered from natural gas through separation equipment or natural gas treatment plants. Propane, normal-butane and isobutane, isopentane and pentane plus, that used to be defined natural gasoline, are natural gas liquids.

Network Code A code containing norms and regulations for access to, management and operation of natural gas pipelines.

Offshore/Onshore The term offshore indicates a portion of open sea and, by induction, the activities carried out in such area, while onshore refers to land operations.
  Olefins (or Alkenes) Hydrocarbons that are particularly active chemically, used for this reason as raw materials in the synthesis of intermediate products and of polymers.

Over/Underlifting Agreements stipulated between partners regulate the right of each to its share in the production of a set period of time. Amounts different from the agreed ones determine temporary over/underlifting situations.

Possible reserves Amounts of hydrocarbons that have a lower degree of certainty than probable reserves and are estimated with lower certainty, for which it is not possible to foresee production.

Probable reserves Amounts of hydrocarbons that are probably, but not certainly, expected to be extracted. They are estimated based on known geological conditions, similar characteristics of rock deposits and the interpretation of geophysical data. Further uncertainty elements may concern: (i) the extension or other features of the field; (ii) economic viability of extraction based on the terms of the development project; (iii) existence and adequacy of transmission infrastructure and/or markets; (iv) the regulatory framework.

Production Sharing Agreement Contract in use in non OECD area countries, regulating relationships between States and oil companies with regard to the exploration and production of hydrocarbons. The mining concession is assigned to the national oil company jointly with the foreign oil company who has exclusive right to perform exploration, development and production activities and can enter agreements with other local or international entities. In this type of contract the national oil company assigns to the international contractor the task of performing exploration and production with the contractor’s equipment and financial resources. Exploration risks are borne by the contractor and production is divided into two portions: “cost oil” is used to recover costs borne by the contractor, “profit oil” is divided between contractor and national company according to variable schemes and represents the profit deriving from exploration and production. Further terms and conditions may vary from one country to the other.

Proved reserves Proved reserves are estimated volumes of crude oil, natural gas and gas condensates, liquids and associated substances which are expected to be

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retrieved from deposits and used commercially, at the economic and technical conditions applicable at the time of the estimate and according to current legislation. Proved reserves include: (i) proved developed reserves: amounts of hydrocarbons that are expected to be retrieved through existing wells, facilities and operating methods; (ii) non developed proved reserves: amounts of hydrocarbons that are expected to be retrieved following new drilling, facilities and operating methods. On these amounts the company has already defined a clear development expenditure program which is expression of the company’s determination.

Recoverable reserves Amounts of hydrocarbons included in different categories of reserves (proved, probable and possible), without considering their different degree of uncertainty.

Reserve replacement ratio Measure of the reserves produced replaced by proved reserves. Indicates the company’s ability to add new reserves through exploration and purchase of property. A rate higher than 100% indicates that more reserves were added than produced in the period. The ratio should be averaged on a three-year period in order to reduce the distortion deriving from the purchase of proved property, the revision of previous estimates, enhanced recovery, improvement in recovery rates and changes in the value of reserves – in PSAs – due to changes in international oil prices. Management also calculates this ratio by excluding the effect of the purchase of proved property in order to better assess the underlying performance of the Company’ s operations.

Ship-or-pay Clause included in natural gas transportation contracts according to which the customer for which the transportation is carried out is bound to pay for the transportation of the gas also in case the gas is not transported.

Strategic Storage Volumes of natural gas required for covering lack or reduction of supplies from extra-European sources or crises in the natural gas system.
  Swap In the gas sector, the swap term is referred to a buy/sell contract between some counterparties and is generally aimed to the optimization of transport costs and respective commitments in purchasing and supplying.

Take-or-pay Clause included in natural gas transportation contracts according to which the purchaser is bound to pay the contractual price or a fraction of such price for a minimum quantity of the gas set in the contract also in case it is not collected by the customer. The customer has the option of collecting the gas paid and not delivered at a price equal to the residual fraction of the price set in the contract in subsequent contract years.

Upstream/Downstream The term upstream refers to all hydrocarbon exploration and production activities. The term downstream includes all activities inherent to the oil sector that are downstream of exploration and production activities.

Wholesale sales Domestic sales of refined products to wholesalers/distributors (mainly gasoil), public administrations and end consumers, such as industrial plants, power stations (fuel oil), airlines (jet fuel), transport companies, big buildings and households. They do not include distribution through the service station network, marine bunkering, sales to oil and petrochemical companies, importers and international organizations.

Workover Intervention on a well for performing significant maintenance and substitution of basic equipment for the collection and transport to the surface of liquids contained in a field.




ABBREVIATIONS

mmcf = million cubic feet
bcf = billion cubic feet
mmcm = million cubic meters
bcm = billion cubic meters
boe = barrel of oil equivalent
kboe = thousand barrel of oil equivalent
mmboe = million barrel of oil equivalent
bboe = billion barrel of oil equivalent
bbl = barrels
kbbl = thousand barrels
mmbbl = million barrels
bbbl = billion barrels
mmtonnes = million tonnes
ktonnes = thousand tonnes
/d = per day
/y = per year

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Report of Independent Auditors

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Consolidated Financial

Statements

 

 

 

 

 

 

 

 

 

 

 

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Balance sheet

    Dec. 31, 2005   Dec. 31, 2006
   
 
(million euro)   Note   Total amount   of which with related parties   Total amount   of which with related parties
       
 
 
 
ASSETS                        
Current assets                        
Cash and cash equivalent   (1)   1,333         3,985      
Other financial assets held for trading or available for sale   (2)   1,368         972      
Trade and other receivables   (3)   17,902     1,344   18,799     1,027
Inventories   (4)   3,563         4,752      
Current tax assets   (5)   697         658      
Other current assets   (6)   369         855      
Total current assets       25,232         30,021      
Non-current assets                        
Property, plant and equipment   (7)   45,013         44,312      
Other assets   (8)             629      
Inventories - Compulsory stock   (9)   2,194         1,827      
Intangible assets   (10)   3,194         3,753      
Investments accounted for using the equity method   (11)   3,890         3,886      
Other investments   (11)   421         360      
Other financial assets   (12)   1,050     258   805     136
Deferred tax assets   (13)   1,861         1,725      
Other non-current receivables   (14)   995         994      
Total non-current assets       58,618         58,291      
TOTAL ASSETS       83,850         88,312      
LIABILITIES AND SHAREHOLDERS’ EQUITY                        
Current liabilities                        
Short-term financial liabilities   (15)   4,612     152   3,400     92
Current portion of long-term debt   (19)   733         890      
Trade and other payables   (16)   13,095     1,164   15,995     961
Taxes payable   (17)   3,430         2,830      
Other current liabilities   (18)   613         634      
Total current liabilities       22,483         23,749      
Non-current liabilities                        
Long-term debt   (19)   7,653         7,409      
Provisions for contingencies   (20)   7,679         8,614      
Provisions for employee benefits   (21)   1,031         1,071      
Deferred tax liabilities   (22)   4,890         5,852      
Other non-current liabilities   (23)   897         418     56
Total non-current liabilities       22,150         23,364      
TOTAL LIABILITIES       44,633         47,113      
SHAREHOLDERS’ EQUITY   (24)                    
Minority interests       2,349         2,170      
Shareholders’ equity:                        
Share capital: 4,005,358,876 fully paid shares with nominal value euro 1 each (same amount as of December 31, 2005)       4,005         4,005      
Share premium                        
Other reserves       10,910         6,013      
Retained earnings       17,381         25,168      
Net profit       8,788         9,217      
Treasury shares       (4,216 )       (5,374 )    
Total Eni shareholders’ equity       36,868         39,029      
TOTAL SHAREHOLDERS’ EQUITY       39,217         41,199      
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY       83,850         88,312      
       

 
 

 

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Profit and loss account

    2005   2006
   
 
(million euro)   Note   Total amount   of which with related parties   Total amount   of which with related parties
       
 
 
 
REVENUES   (26)                    
Net sales from operations       73,728     4,535   86,105     3,974
Other income and revenues       798         783      
Total revenues       74,526         86,888      
OPERATING EXPENSES   (27)                    
Purchases, services and other       48,567     3,429   57,490     2,720
- of which significant non recurring events and operations   (34)   290         239      
Payroll and related costs       3,351         3,650      
Depreciation, amortization and impairments       5,781         6,421      
OPERATING PROFIT       16,827         19,327      
FINANCIAL INCOME (EXPENSE)   (28)                    
Financial income       3,131     72   4,132     58
Financial expense       (3,497 )       (3,971 )    
        (366 )       161      
Income (expense) from investments   (29)                    
Effects of investments accounted for using the equity method       737         795      
Other income (expense) from investments       177         108      
        914         903      
PROFIT BEFORE INCOME TAXES       17,375         20,391      
Income taxes   (30)   (8,128 )       (10,568 )    
Net profit       9,247         9,823      
                         
Pertaining to:                        
- Eni       8,788         9,217      
- minority interest   (24)   459         606      
        9,247         9,823      
Earnings per share pertaining to Eni (euro per share)   (31)                    
- basic       2.34         2.49      
- diluted       2.34         2.49      
       

 
 

 

 

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Statements of changes in shareholders’ equity

 

Eni shareholders’ equity

 
 
 
(million euro)  

Share capital

 

Legal reserve of Eni SpA

 

Reserve for treasury shares

 

Other reserves

 

Cumulative translation exchange differences reserve

 

Treasury shares

 

Retained earnings

 

Interim dividend

 

Net profit for the year

 

Total

 

Minority interests

 

Total shareholders’ equity

   
 
 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2004   4,004     959     5,392     3,965     (687 )   (3,229 )   14,911           7,059     32,374     3,166     35,540  
Changes in accounting principles (IAS 32 and 39)                     13                 (40 )               (27 )   12     (15 )
Adjusted balance at January 1, 2005   4,004     959     5,392     3,978     (687 )   (3,229 )   14,871           7,059     32,347     3,178     35,525  
Net profit of the year (note 24)                                                   8,788     8,788     459     9,247  
Net income (expense) directly recognized in equity:                                                                        
Change in the fair value of financial assets for trading (note 24)                     6                                   6           6  
Change in the fair value of cash flow hedge derivatives (note 24)                     16                                   16           16  
Exchange differences from translation of financial statements denominated in currencies other than the euro                           1,497                             1,497     15     1,512  
                      22     1,497                             1,519     15     1,534  
Total (expense) income of the year                     22     1,497                       8,788     10,307     474     10,781  
Transactions with shareholders:                                                                        
Dividend distribution of Eni SpA (euro 0.90 per share)                                                   (3,384 )   (3,384 )         (3,384 )
Interim dividend (euro 0.45 per share)                                             (1,686 )         (1,686 )         (1,686 )
Dividend distribution of other companies                                                               (1,218 )   (1,218 )
Allocation of 2004 residual net profit                     1,300                 2,375           (3,675 )                  
Shares repurchased                                 (1,034 )                     (1,034 )         (1,034 )
Shares issued under stock grant plans   1                 (1 )                                                
Treasury shares sold under incentive plans for Eni managers               (47 )   47           47                       47           47  
    1           (47 )   1,346           (987 )   2,375     (1,686 )   (7,059 )   (6,057 )   (1,218 )   (7,275 )
Other changes in shareholders’ equity                                                                        
Cost related to stock options                     5                                   5           5  
Sale of consolidated companies                                                               (40 )   (40 )
Exchange differences arising on the distribution of dividends and other changes                           131           135                 266     (45 )   221  
                      5     131           135                 271     (85 )   186  
Balance at December 31, 2005 (note 24)   4,005     959     5,345     5,351     941     (4,216 )   17,381     (1,686 )   8,788     36,868     2,349     39,217  
   

 

 

 

 

 

 

 

 

 

 

 

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Statements of changes in shareholders’ equity (continued)

 

Eni shareholders’ equity

 
 
 
(million euro)  

Share capital

 

Legal reserve of Eni SpA

 

Reserve for treasury shares

 

Other reserves

 

Cumulative translation exchange differences reserve

 

Treasury shares

 

Retained earnings

 

Interim dividend

 

Net profit for the year

 

Total

 

Minority interests

 

Total shareholders’ equity

   
 
 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2005 (note 24)   4,005     959     5,345     5,351     941     (4,216 )   17,381     (1,686 )   8,788     36,868     2,349     39,217  
Net profit of the year (note 24)                                                   9,217     9,217     606     9,823  
Net income (expense) directly recognized in equity:                                                                        
Change in the fair value of financial assets for trading (note 24)                     (13 )                                 (13 )         (13 )
Change in the fair value of cash flow hedge derivatives (note 24)                     (15 )                                 (15 )         (15 )
Exchange differences from translation of financial statements denominated in currencies other than the euro                           (1,266 )                           (1,266 )   (29 )   (1,295 )
                      (28 )   (1,266 )                           (1,294 )   (29 )   (1,323 )
Total (expense) income of the year                     (28 )   (1,266 )                     9,217     7,923     577     8,500  
Transactions with shareholders:                                                                        
Dividend distribution of Eni SpA (euro 0.65 per share in settlement of 2005) interim dividend of euro 0.45 per share) (note 24)                                             1,686     (4,086 )   (2,400 )         (2,400 )
Dividend distribution of Eni SpA (euro 0.60 per share) (note 24)                                             (2,210 )         (2,210 )         (2,210 )
Dividend distribution of other companies                                                               (222 )   (222 )
Payments by minority shareholders                                                               22     22  
Allocation of 2005 net profit                                       4,702           (4,702 )                  
Authorization to shares repurchase (note 24)               2,000                       (2,000 )                              
Shares repurchased (note 24)                                 (1,241 )                     (1,241 )         (1,241 )
Treasury shares sold under incentive plans for Eni managers (note 24)               (85 )   54           85     21                 75           75  
Difference between the book value and strike price of stock options exercised by Eni managers                                       7                 7           7  
                1,915     54           (1,156 )   2,730     (524 )   (8,788 )   (5,769 )   (200 )   (5,969 )
Other changes in shareholders’ equity:                                                                        
Sale of Snamprogetti SpA to Saipem Projects SpA                     247                                   247     (247 )      
Net effect related to the purchase of treasury shares by Saipem SpA and Snam Rete Gas SpA                                                               (306 )   (306 )
Purchase and sale of consolidated companies to third parties                                                               (5 )   (5 )
Cost related to stock options                                       14                 14           14  
Reclassification of reserves of Eni SpA               2     (5,224 )         (2 )   5,224                                
Exchange differences arising on the distribution of dividends and other changes                           (73 )         (181 )               (254 )   2     (252 )
                2     (4,977 )   (73 )   (2 )   5,057                 7     (556 )   (549 )
Balance at December 31, 2006 (note 24)   4,005     959     7,262     400     (398 )   (5,374 )   25,168     (2,210 )   9,217     39,029     2,170     41,199  
   

 

 

 

 

 

 

 

 

 

 

 

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Statements of cash flow

(million euro)  

    Note 

 

2005

 

2006

       
 
Net profit of the year       9,247     9,823  
Depreciation and amortization   (27)   5,509     6,153  
Revaluations, net       (288 )   (386 )
Net change in the provisions for contingencies       1,279     (86 )
Net change in the provisions for employee benefits       18     72  
Gain on disposal of assets, net       (220 )   (59 )
Dividend income   (29)   (33 )   (98 )
Interest income       (214 )   (387 )
Interest expense       654     346  
Exchange differences       (64 )   6  
Income taxes   (30)   8,128     10,568  
Cash generated from operating profit before changes in working capital       24,016     25,952  
(Increase) decrease:                
- inventories       (1,402 )   (953 )
- trade and other receivables       (4,413 )   (1,952 )
- other assets       351     (315 )
- trade and other payables       3,030     2,146  
- other liabilities       12     50  
Cash from operations       21,594     24,928  
Dividends received       366     848  
Interest received       214     395  
Interest paid       (619 )   (294 )
Income taxes paid       (6,619 )   (8,876 )
Net cash provided from operating activities       14,936     17,001  
- of which with related parties   (33)   1,230     2,206  
Investments:                
- tangible assets   (7)   (6,558 )   (6,138 )
- intangible assets   (10)   (856 )   (1,695 )
- consolidated subsidiaries and businesses       (73 )   (46 )
- investments   (11)   (54 )   (42 )
- securities       (464 )   (49 )
- financing receivables       (683 )   (516 )
- change in payables and receivables in relation                
to investments and capitalized depreciation       149     (26 )
Cash flow from investments       (8,539 )   (8,512 )
Disposals:                
- tangible assets       99     237  
- intangible assets       13     12  
- consolidated subsidiaries and businesses       252     8  
- investments       178     36  
- securities       369     382  
- financing receivables       804     794  
- change in payables and receivables in relation to disposals       9     (8 )
Cash flow from disposals       1,724     1,461  
Net cash used in investing activities (*)       (6,815 )   (7,051 )
- of which with related parties   (33)   (160 )   (686 )
       

 

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Statements of cash flow (continued)

(million euro)  

    Note 

 

2005

 

2006

       
 
Proceeds from long-term debt       2,755     2,888  
Payments of long-term debt       (2,978 )   (2,621 )
Reductions of short-term debt       (317 )   (949 )
        (540 )   (682 )
Net capital contributions by minority shareholders       24     22  
Net acquisition of treasury shares different from Eni SpA       (30 )   (477 )
Acquisition of additional interests in consolidated subsidiaries       (3 )   (7 )
Sale of additional interests in consolidated subsidiaries             35  
Dividends to minority shareholders       (6,288 )   (4,832 )
Net purchase of treasury shares       (987 )   (1,156 )
Net cash used in financing activities       (7,824 )   (7,097 )
- of which with related parties   (33)   23     (57 )
Effect of changes in consolidation       (38 )   (4 )
Effect of exchange differences       71     (197 )
Net cash flow for the period       330     2,652  
Cash and cash equivalent at beginning of the year   (1)   1,003     1,333  
Cash and cash equivalent at end of the year   (1)   1,333     3,985  
       

 

     
(*)   Net cash used in investing activities includes some investments which Eni, due to their nature (temporary cash investments or carried out in order to optimize management of treasury operations) are considered as a reduction in net borrowings as defined in the "Financial Review" in the "Report of the Directors". Cash flow of such investments are as follows:
     
(million euro)  

    

 

2005

 

2006

       
 
Financing investments:            
- securities   (186 )   (44 )
- financing receivables   (45 )   (134 )
    (231 )   (178 )
Disposal of financing investments:            
- securities   60     340  
- financing receivables   62     54  
    122     394  
Net cash flows from financing activities   (109 )   216  
   

 

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SUPPLEMENTAL CASH FLOW INFORMATION

(million euro)  

   

 

2005

 

2006

       
 
Effect of investment of companies included in consolidation and businesses            
Current assets         68  
Non-current assets   122     130  
Net borrowings   (19 )   53  
Current and non-current liabilities   (22 )   (92 )
Net effect of investments   81     159  
Sale of unconsolidated subsidiaries         (60 )
Fair value of the participations held before the acquisition of control   (8 )      
Purchase price   73     99  
less:            
Cash and cash equivalent         (53 )
Cash flow on investments   73     46  
Effect of disposal of consolidated subsidiaries and businesses            
Current assets   204     9  
Non-current assets   189     1  
Net borrowings   42     (1 )
Current and non-current liabilities   (217 )   (4 )
Net effect of disposals   218     5  
Gain on disposals   140     3  
Minority interest   (43 )      
Selling price   315     8  
less:            
Cash and cash equivalent   (63 )      
Cash flow on disposal   252     8  
   

 

 

Transactions that did not produce cash flows
Acquisition of equity investments in exchange of businesses:

(million euro)  

   

 

2005

 

2006

       
 
Effect of business contributions            
Current assets   2     23  
Non-current assets   17     213  
Net borrowings         (44 )
Long-term and short-term liabilities   (1 )   (53 )
Net effect of contributions   18     139  
Minority interest         (36 )
Gain on contributions         18  
Acquisition of investments   18     121  
   

 

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Basis of presentation

The Consolidated Financial Statements of Eni have been prepared in accordance with IFRS issued by the International Accounting Standards Board (IASB) and adopted by the European Commission following the procedure contained in Article 6 of the EC Regulation No. 1606/2002 of the European Parliament and Council of July 19, 2002 and in accordance with Article 9 of Legislative Decree No. 38/2005. For hydrocarbon exploration and production, accounting policies followed at an international level have been applied, with particular reference to amortization according to the Unit-Of-Production method, buy-back contracts and Production Sharing Agreements.
The Consolidated Financial Statements have been prepared by applying the cost method except for items that under IFRS must be recognized at fair value as described in the evaluation criteria.
The Consolidated Financial Statements include the statutory accounts of Eni SpA and of all Italian and foreign companies in which Eni SpA holds the right to directly or indirectly exercise control, determine financial and management decisions and obtain economic and financial benefits.
Insignificant subsidiaries are not included in the scope of consolidation. A subsidiary is considered insignificant when it does not exceed two of these limits: (i) total assets or liabilities: euro 3,125 thousand; (ii) total revenues: euro 6,250 thousand; (iii) average number of employees: 50 units. Moreover, companies for which consolidation does not produce significant economic and financial effects are not included in the scope of consolidation. Such companies generally represent subsidiaries that work on account of other companies as the sole operator in the management of upstream oil contracts; these companies are financed on a proportional basis according to budgets approved, by the companies involved in the project, to which the company periodically reports costs and receipts deriving from the contract. Costs and revenues and other operating data (production, reserves, etc.) of the project, as well as the obligations arising from the project, are recognized proportionally in the Financial Statements of the companies involved. The effects of these exclusions are not material1.
Subsidiaries excluded from consolidation, joint ventures, associates and other interests are accounted for as described below under item “Financial fixed assets”.
Financial Statements of consolidated companies are audited by auditing companies that examine and certify the information required to be disclosed when preparing the consolidated financial statement.
Considering their materiality, amounts of the financial statements and related disclosures are expressed in millions of euro.


Principles of consolidation

Interests in companies included in the scope of consolidation
Assets and liabilities, expense and income related to fully consolidated companies are wholly incorporated into the Consolidated Financial Statements; the book value of these interests is eliminated against the corresponding fraction of the shareholders’ equity of the companies owned, attributing to each item of the balance sheet the current value at the date of acquisition of control. Any positive residual difference as regards to the acquisition cost is recognized as “Goodwill”. Negative residual differences are charged against the profit and loss account.
Any positive residual difference between cost for the acquisition of the share that exceed the control (minorities acquisition) and corresponding fraction of shareholders’ equity acquired is recognized as “Goodwill”.
Gains or losses on the sale of shares in consolidated subsidiaries are recorded in the profit and loss account for the amount corresponding to the difference between proceeds from the sale and divested portion of net equity sold.
Fractions of shareholders’ equity and net profit of minority interest are recognized under specific items in the Financial Statements. Minority interest is determined based on the current value attributed to assets and liabilities at the date of the acquisition of control, excluding any related goodwill.

Inter-company transactions
Income deriving from inter-company transactions unrealized towards third parties is eliminated. Receivables, payables, revenues and costs, guarantees, commitments and risks among consolidated companies are eliminated as well. Inter-company losses are not eliminated, since they reflect an actual decrease in the value of divested assets.


     
(1)   According to the requirements of the framework of international accounting standards, information is material if its omission or misstatement can influence the economic decisions that users make on the basis of the financial statements.

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Foreign currency translation
Financial Statements of consolidated companies denominated in currencies other than the euro are converted into euro applying exchange rates prevailing at the year end to assets and liabilities, the historical exchange rates to equity accounts and the average rates for the period to profit and loss account (source: Ufficio Italiano Cambi).
Exchange rate differences from the conversion deriving from the application of different exchange rates for assets and liabilities, shareholders’ equity and profit and loss account are recognized under the item “Other reserves” within shareholders’ equity for the portion relating to the Group and under the item “Minority interest” for the portion related to minority shareholders. The exchange rate differences reserve is charged to the profit and loss account when the investments are sold or the capital employed is repaid.
Financial Statements of foreign subsidiaries which are translated into euro are denominated in the functional currencies of the country where the enterprise operates. The US dollar is the prevalent functional currency for the enterprises that do not adopt the euro.



Evaluation criteria

The most significant evaluation criteria used for the preparation of the Consolidated Financial Statements are shown below.

Current assets
Financial assets held for trading and financial assets available for sale are stated at fair value; economic effects are charged to the profit and loss account item “Financial Income (Expense)” and under shareholders’ equity within “Other reserves”. In the last case, changes in fair value recognized under shareholders’ equity are charged to the profit and loss account when they are impaired or realized.
The fair value of financial instruments is represented by market quotations or, in their absence, by the value resulting from the adoption of suitable financial valuation models which take into account all the factors adopted by the market operators and the prices obtained in similar actual transactions in the market.
When the conditions for the purchase or sale of financial assets provide for the settlement of the transaction and the delivery of the assets within a given number of days determined by entities controlling the market or by agreements (e.g., purchase of securities on regulated markets), the transaction is entered at the date of settlement.
Receivables are stated at their amortized cost (see item “Financial fixed assets” below).
Transferred financial assets are eliminated when the transaction, together with the cash flows deriving from it, leads to the substantial transfer of all risks and benefits associated to the property.
Inventories, excluding contract work in progress and including compulsory stocks, are stated at the lower of purchase or production cost and net realizable value represented by the proceeds the company expects to collect from the sale of the inventories in the normal course of business.
The cost of inventories of hydrocarbons (crude oil, condensates and natural gas) and petroleum products is determined by applying the weighted-average cost method on a three-month basis; the cost of inventories of the Petrochemical segment is determined by applying the weighted-average cost on an annual basis.
Contract work in progress is recorded on the basis of contractual considerations by reference to the stage of completion of a contract measured on a cost-to-cost basis. Advances are deducted from inventories within the limits of contractual considerations; any excess of such advances over the value of the work performed is recorded as a liability. Losses related to construction contracts are accrued for once the company becomes aware of such losses. Contract work in progress not yet invoiced, whose payment is agreed in a foreign currency, is translated to euro using the current exchange rates at year end and effects are charged in the profit and loss account.
Hedging instruments are described in the section “Derivative Instruments”.

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Non-current assets

Property, plant and equipment2
Tangible assets, including investment properties, are recognized using the cost model and stated at their purchase or production cost including ancillary costs which can be directly attributed to them as required to make the asset ready for use. In addition, when a substantial amount of time is required to make the asset ready for use, the purchase price or production cost includes the financial expenses incurred that would have theoretically been saved if the investment had not been made.
In the case of current obligations for the dismantling and removal of assets and the reclamation of sites, the carrying value includes, with a corresponding entry to a specific provision, the estimated (discounted) costs to be borne at the moment the asset is retired. Revisions of estimates for these provisions, for the passage of time and for changes in the discount rate are recognized under “Provisions for contingencies”3.
No revaluation is made even in application of specific laws.
Assets carried under financial leasing or concerning arrangements that does not take the legal form of a financial lease but produce a substantive transfer of risks and rewards of ownership, are recognized at fair value, net of taxes due from the lessor or, if lower, at the amount of future minimum lease payments, and are included within the tangible assets, with a corresponding entry to the financial payable to the lessor, and depreciated using the criteria detailed below. When the renewal is not reasonably certain, assets carried under financial leasing are depreciated over the period of the lease if shorter than the useful life of the asset.
Renewals, improvements and transformations which extend asset lives are capitalized.
Tangible assets, commencing on the date when they begin or should begin to be used, are depreciated systematically based on the straight-line method over the duration of their useful life taken as an estimate of the period for which the assets will be used by the company. When tangible asset are comprised of more than one significant element with different useful lives, the depreciation is carried out for each component. The amount to be depreciated is represented by the book value reduced by the presumable net realizable value at the end of the useful life, if it is significant and can be reasonably determined. Land is not depreciated, even if purchased together with a building. Tangible assets held for sales are not depreciated but are valued at the lower of the book value and fair value less costs of disposal.
Assets that can be used free of charge are depreciated over the shorter term of the duration of the concession and the useful life of the asset.
The costs for the substitution of identifiable components in complex assets are capitalized and depreciated over their useful life; the residual book value of the component that has been substituted is charged to the profit and loss account. Ordinary maintenance and repair costs are expensed when incurred.
When events occur that lead to a presumable reduction in the book value of tangible assets, their recoverability is checked by comparing their book value with the realizable value, represented by the greater of fair value less costs of disposal and value in use. In the absence of a binding sales agreement, fair value is estimated on the basis of market values, recent transactions, or the best available information that shows the proceeds that the company could reasonably expect to collect from the disposal of asset. Value in use is determined by discounting the expected cash flows deriving from the use of the asset and, if significant and reasonably determinable, the cash flows deriving from its disposal at the end of its useful life, net of disposal costs. Cash flows are determined on the basis of reasonable and documented assumptions that represent the best estimate of the future economic conditions during the residual useful life of the asset, giving more importance to independent assumptions. Discounting is carried out at a rate that takes into account the implicit risk in the sectors where the entity operates. Valuation is carried out for each single asset or, if the realizable value of a single asset cannot be determined, for the smallest identifiable group of assets that generates independent cash inflows from their continuous use, the so called “cash generating unit”. When the reasons for their impairment cease to exist, Eni reverses previously recorded impairment charges and records as income of an asset revaluation in the profit and loss account for the relevant year. This asset revaluation is the lower of the fair value and the book value increased by the amount of previously incurred impairments net of related amortization that would have been made if the impairment had not been made.


     
(2)   Recognition and evaluation criteria of exploration and production activities are described in the section “Exploration and production activities” below.
(3)   The company recognizes material provisions for the retirement of assets in the Exploration & Production business. No significant asset retirement obligations associated with any legal obligations to retire refining, marketing and transportation (downstream) and chemical long-lived assets generally are recognized, as indeterminate settlement dates for the asset retirements prevented estimation of the fair value of the associated asset retirement obligation. The company performs periodic reviews of its downstream and chemical long-lived assets for any changes in facts and circumstances that might require recognition of a retirement obligation.

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Intangible assets
Intangible assets include assets which lack identifiable physical qualities, controlled by the company and able to produce future economic benefits, and goodwill acquired in business combinations. An asset is classified as intangible when the management is able to distinguish it clearly from goodwill. This condition is normally met when: (i) the intangible asset can be traced back to a legal or contractual right, or (ii) the asset is separable, i.e., can be sold, transferred, licensed, rented or exchanged, either individually or as an integral part of other assets. An entity controls an asset if it has the power to obtain the future economic benefits flowing from the underlying resource and to restrict the access of others to those benefits.
Intangible assets are stated at cost as determined with the criteria used for tangible assets. No revaluation is made even in application of specific laws.
Intangible assets with a defined useful life are amortized systematically over the duration of their useful life taken as an estimate of the period for which the assets will be used by the company; the recoverability of their book value is checked using the criteria described in the section “Tangible Assets”.
Goodwill and other intangible assets with an indefinite useful life are not amortized. The recoverability of their carrying value is checked at least annually and whenever events or changes in circumstances indicate that the carrying value may not be recoverable. With reference to goodwill, this check is performed at the level of the smallest aggregate on which the company, directly or indirectly, evaluates the return on the capital expenditure that included said goodwill. When the carrying amount of the cash generating unit, including goodwill attributed thereto, exceeds the cash generating unit's recoverable amount, the difference is recognized as impairment and it is primarily charged against goodwill up to its amount; any amount in excess is charged on a pro-rata basis against the book value of the assets that form the cash generating unit. Impairment charges against goodwill are not revalued. Negative goodwill is recognized in the profit and loss account.
Costs of technological development activities are capitalized when: (i) the cost attributable to the intangible asset can be reasonably determined; (ii) there is the intention, availability of funding and technical capacity to make the asset available for use or sale; and (iii) it can be shown that the asset is able to produce future economic benefits.

Exploration and production activities4

ACQUISITION OF MINERAL RIGHTS
Costs associated with the acquisition of mineral rights are capitalized in connection with the assets acquired (such as exploratory potential, probable and possible reserves and proved reserves). When the acquisition is related to a set of exploratory potential and reserves, the cost is allocated to the different assets acquired on the basis of the value of the relevant discounted cash flows.
Expenditure for the exploratory potential, represented by the costs for the acquisition of the exploration permits and for the extension of existing permits, is recognized under “Intangible Assets” and is amortized on a straight-line basis over the period of the exploration as contractually established. If the exploration is abandoned, the residual expenditure is charged to the profit and loss account.
Acquisition costs for proved reserves and for possible and probable reserves are recognized in the balance sheet as assets. Costs associated with proved reserves are amortized on a Unit of Production (UoP) basis, as detailed in the section “Development”, considering both developed and undeveloped reserves. Expenditures associated with possible and probable reserves are not amortized until classified as proved reserves; in case of a negative result, the costs are charged to the profit and loss account.

EXPLORATION
Costs associated with exploratory activities for oil and gas producing properties incurred both before and after the acquisition of mineral rights (such as acquisition of seismic data from third parties, test wells and geophysical surveys) are capitalized, to reflect their nature of investment and amortized in full when incurred.

DEVELOPMENT
Development costs are those costs incurred to obtain access to proved reserves and to provide facilities for extracting, gathering and storing oil and gas. They are then capitalized and amortized generally on a UoP basis, as their useful life is closely related to the availability of feasible reserves. This method provides for residual costs at the end of each quarter to be amortized through a rate representing the ratio between the volumes extracted during the quarter and the proved developed reserves existing at the end of the quarter, increased by the volumes extracted during the quarter. This method is applied with reference to the smallest aggregate representing a direct correlation between investment and proved developed reserves.

     
(4)   International accounting principles do not establish specific criteria for hydrocarbon exploration and production activities. Eni continues to use existing accounting policies for exploration and evaluation assets previously applied before the introduction of IFRS, as permitted by IFRS 6 “Exploration for and evaluation of mineral resources”.

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Costs related to unsuccessful development wells or damaged wells are expensed immediately as losses on disposal.
Impairments and reversal of impairments of development costs are made on the same basis as those for tangible assets.

PRODUCTION
Production costs are those costs incurred to operate and maintain wells and field equipment and are expensed as incurred.

PRODUCTION SHARING AGREEMENTS AND BUY-BACK CONTRACTS
Revenues and oil and gas reserves related to Production Sharing Agreements and buy-back contracts are settled on the basis of contractual clauses related to the repayment of costs incurred following the exploration, development and operating activities (cost oil) and to the relevant amount of realized productions (profit oil).

RETIREMENT
Costs expected to be incurred with respect to the retirement of a well, including costs associated with removal of production facilities, dismantlement and site restoration, are capitalized and amortized on a UOP basis, consistent with the policy described under “Tangible Assets”.

Grants
Grants related to assets are recorded as a reduction of purchase price or production cost of the related assets when there is reasonable assurance that all the required conditions attached to them, agreed upon with governmental entities, have been met. Grants not related to capital expenditure are recognized in the profit and loss account.

Financial fixed assets

INVESTMENTS
Investments in subsidiaries excluded from consolidation, joint ventures and associates are accounted for using the equity method. If it does not result in a misrepresentation of the company’s financial condition and consolidated results, subsidiaries, joint ventures and associates excluded from consolidation may be accounted for at cost, adjusted for impairment losses. When the reasons for their impairment cease to exist, investments accounted for at cost are revalued within the limit of the impairment made and their effects are charged to the profit and loss account item “Other income (expense) from investments”.
Other investments are recognized at their fair value and their effects are included in shareholders’ equity under “Other reserves”; this reserve is charged to the profit and loss account when it is impaired or realized. When fair value cannot be reasonably ascertained, investments are accounted for at cost, adjusted for impairment losses; impairment losses may not be revalued.
The risk deriving from losses exceeding shareholders’ equity is recognized in a specific provision to the extent the parent company is required to fulfill legal or implicit obligations towards the subsidiary or to cover its losses.

RECEIVABLES AND FINANCIAL ASSETS TO BE HELD TO MATURITY
Receivables and financial assets that must be held to maturity are stated at cost represented by the fair value of the initial exchanged amount adjusted to take into account direct external costs related to the transaction (e.g., fees of agents or consultants, etc.). The initial carrying value is then corrected to take into account capital repayments, impairments and amortization of the difference between the reimbursement value and the initial carrying value; amortization is carried out on the basis of the effective internal rate of return represented by the rate that equalizes, at the moment of the initial revaluation, the current value of expected cash flows to the initial carrying value (so-called amortized cost method). Any impairment is recognized by comparing the carrying value with the present value of the expected cash flows discounted at the effective interest rate defined at the initial recognition. The economic effects of the valuation according to the amortized cost method are charged to “Financial income (expense)”.

Financial liabilities
Debt is carried at amortized cost (see item “Financial fixed assets” above).

Provisions for contingencies
Provisions for contingencies concern risks and charges of a definite nature and whose existence is certain or probable but for which at year end the amount or date of occurrence remains uncertain. Provisions are made when: (i) there is a current obligation,

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either legal or implicit, deriving from a past event; (ii) it is probable that the fulfillment of that obligation will result in an outflow of resources embodying economic benefits; and (iii) the amount of the obligation can be reliably estimated. Provisions are stated at the value that represents the best estimate of the amount that the company would reasonably pay to fulfill the obligation or to transfer it to third parties at year end. When the financial effect of time is significant and the payment date of the obligations can be reasonably estimated, the provisions are discounted back at the company’s average rate of indebtedness. The increase in the provision due to the passing of time is charged to the profit and loss account in the item “Financial Income (Expense)”.
When the liability regards a tangible asset (e.g., site restoration and abandonment), the provision is stated with a corresponding entry to the asset to which it refers; profit and loss account charge is made with the amortization process.
Costs that the company expects to bear in order to carry out restructuring plans are recognized in the year in which the company formally defines the plan and the interested parties have developed the reasonable expectation that the restructuring will happen.
Provisions are periodically updated to show the variations of estimates of costs, production times and actuarial rates; the estimated revisions to the provisions are recognized in the same profit and loss account item that had previously held the provision, or, when the liability regards tangible assets (i.e., site restoration and abandonment) with a corresponding entry to the assets to which they refer.

In the Notes to the Consolidated Financial Statements the following potential liabilities are described: (i) possible, but not probable obligations deriving from past events, whose existence will be confirmed only when one or more future events beyond the company’s control occur; and (ii) current obligations deriving from past events whose amount cannot be reasonably estimated or whose fulfillment will probably not result in an outflow of resources embodying economic benefits.

Employee benefits
Post-employment benefit plans are defined on the basis of plans, including those unformalized, that due to their terms defined contributions or defined benefits. In the first case, the company’s obligation, which consists of making payments to the State or a trust or a fund, is determined on the basis of contributions due.
The liabilities related to defined benefit plans5, net of any plan assets, are determined on the basis of actuarial assumptions and charged on accrual basis during the employment period required to obtain the benefits; the evaluation of liabilities is made by independent actuaries.
The actuarial gains and losses of defined benefit plans, deriving from a change in the actuarial assumptions used or from a change in the conditions of the plan, are charged to the profit and loss account, proportionally through the residual average working life of the employees participating to the plan, in the limits of the share of the discounted profit/loss not charged beforehand, that exceeds the greater of 10% of the fair value of liabilities and 10% of the fair value of the plan assets (corridor method).
Obligations for long-term benefits are determined by adopting actuarial assumptions; the effect of changes in actuarial assumptions or a change in the characteristics of the benefit are charged to the profit or loss in their entirety.

Treasury shares
Treasury shares are recorded at cost and as a reduction of shareholders’ equity. Gains following subsequent sales are recorded as an increase in shareholders’ equity.

Revenues and costs
Revenues from sales of products and services rendered are recognized upon transfer of risks and rewards associated to ownership or upon settlement of the transaction. In particular, revenues are recognized:


     
(5)   Given the uncertainties related to their payment date, employees termination indemnities are considered as a defined benefit plan.

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Revenues are recognized upon shipment when, at that date, the risks of loss are transferred to the acquirer. Revenues from the sale of crude oil and natural gas produced in properties in which Eni has an interest together with other producers are recognized on the basis of Eni’s working interest in those properties (entitlement method). Differences between Eni’s net working interest volume and actual production volumes are recognized at current prices at period end.
Income related to partially rendered services are recognized with respect to the accrued revenues, if it is possible to reasonably determine the state of completion and there are no relevant uncertainties concerning the amounts and the existence of the revenue and related costs; otherwise it is recognized within the limits of the recoverable costs incurred.
Revenues accrued in the period related to construction contracts are recognized on the basis of contractual revenues by reference to the stage of completion of a contract measured on the cost-to-cost basis. Requests of additional revenues, deriving from a change in the scope of the work, are included in the total amount of revenues when it is probable that the customer will approve the variation and the related amount; claims deriving for instance from additional costs incurred for reasons attributable to the client are included in the total amount of revenues when it is probable that the counterpart will accept them.
Revenues are stated net of returns, discounts, rebates and bonuses, as well as directly related taxation. Exchanges of goods and services with similar nature and value do not give rise to revenues and costs as they do not represent sale transactions.
Costs are recognized when the related goods and services are sold, consumed or allocated, or when their future useful lives cannot be determined. Costs related to the amount of emissions, determined on the basis of the average prices of the main European markets at the end of the period, are reported in relation to the amount of the carbon dioxide emissions that exceed the amount assigned; revenues related to the amount of emissions are reported when are recognized following the sale.
Operating lease payments are recognized in the profit and loss account over the length of the contract.
Labor costs include stock grants and stock options granted to managers, consistent with their actual remunerative nature. The cost is determined based on the fair value of the rights awarded to the employee at the date of the award and it is not subject to subsequent adjustments; the portion on an accrual basis is calculated pro rata over the period to which the incentive refers (vesting period)6. The fair value of stock grants is represented by the current value of the shares at the date of the award, reduced by the current value of the expected dividends in the vesting period. The fair value of stock options is the value of the option calculated with appropriate valuation techniques that take into account the exercise conditions, current price of the shares, expected volatility and the risk-free interest rate. The fair value of the stock grants and stock options is shown as a contra-entry to “Other reserves”.
The costs for the acquisition of new knowledge or discoveries, the study of products or alternative processes, new techniques or models, the planning and construction of prototypes or, in any case, costs borne for other scientific research activities or technological development, which do not satisfy conditions for the recognition in the balance sheet, are generally considered current costs and expensed as incurred.

Exchange rate differences
Revenues and costs concerning transactions in currencies other than the functional currency are stated at the exchange rate on the date that the transaction is completed.
Monetary assets and liabilities in currencies other than the functional currency are converted by applying the year end exchange rate and the effect is stated in the profit and loss account. Non-monetary assets and liabilities in currencies other than functional currency valued at cost are stated at the initial exchange rate; when they are evaluated at recoverable value or realizable value, the exchange rate applied is that of the day of recognition.

Dividends
Dividends are recognized at the date of the general shareholders’ meeting in which they were declared, except when the sale of shares before the ex-dividend date is certain.

Income taxes
Current income taxes are determined on the basis of estimated taxable income; the estimated liability is recognized in the item “Income tax liabilities”. Current tax assets and liabilities are measured at the amount expected to be paid to (recovered from) the tax authorities, using the tax rates (and tax laws) that have been enacted or substantively enacted at the balance sheet date.


     
(6)   For stock grants, the period between the date of the award and the date of assignation of stock; for stock options, the period between the date of the award and the date on which the option can be exercised.

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Deferred tax assets or liabilities are provided on temporary differences arising between the carrying amounts of the assets and liabilities in the Financial Statements and their tax bases. Deferred tax assets are recognized when their realization is considered probable.
Deferred tax assets and liabilities are recorded under non-current assets and liabilities and are offset at a single entity level if related to offsettable taxes. The balance of the offset, if positive, is recognized in the item “Deferred tax assets”; if negative, in the item “Deferred tax liabilities”. When the results of transactions are recognized directly in the shareholders’ equity, current taxes, deferred tax assets and liabilities are also charged to the shareholders’ equity.

Derivatives
Derivatives, including embedded derivatives which are separated from the host contract, are assets and liabilities recognized at their fair value which is estimated by using the criteria described in the section “Current Assets”.
Derivatives are classified as hedging instruments when the relationship between the derivative and the subject of the hedge is formally documented and the effectiveness of the hedge is high and is checked periodically. When hedging instruments cover the risk of variation of the fair value of the hedged item (fair value hedge, e.g., hedging of the variability on the fair value of fixed interest rate assets/liabilities), the derivatives are stated at fair value and the effects charged to the profit and loss account. Hedged items are consistently adjusted to reflect the variability of fair value associated with the hedged risk. When derivatives hedge the cash flow variation risk of the hedged item (cash flow hedge, e.g., hedging the variability on the cash flows of assets/liabilities as a result of the fluctuations of exchange rate), changes in the fair value of the derivatives, considered effective, are initially stated in net equity and then recognized in the profit and loss account consistently with the economic effects produced by the hedged transaction. The changes in the fair value of derivatives that do not meet the conditions required to qualify as hedging instruments are shown in the profit and loss account.

Financial statements
Assets and liabilities of the balance sheet are classified as current and non-current. Items of the profit and loss account are presented by nature.
Statements of changes in shareholders' equity present profit and loss for the year and other changes of the shareholders' equity.
Statements of cash flows are presented using the indirect method, whereby net profit is adjusted for the effects of transactions of a non-cash nature.


Changes in accounting principles

Since 2006, Eni applies: (i) the requirements of IFRIC 4 “Determining whether an arrangement contains a lease” that provides guidance for determining whether arrangements that do not take the legal form of a lease but which convey rights to use assets in return for a payment or series of payments should be treated as a lease; (ii) the amendments to IAS 39 “Financial instruments: recognition and measurement” that are related to: (a) the possibility to qualify as hedging instruments, in relation to cash flow hedge operations on exchange rate risk realting to inter-company transactions expected and with a high probability, on condition that these transactions are denominated in a functional currency other than the currency of the entity that carries out the operation and the exposure to the exchange rate risk has a potential effect on consolidated profit and loss account; (b) the recognition and measurement of financial guarantees that are recorded when they are issued as a liability valued at market value and then, in relation to the execution risk, at the greater of the best estimate of the charge to be sustained to fulfill the obligation and the initial amount reduced by premiums collected; (iii) the requirements of IFRIC 5 “Rights to interests arising from decommissioning, restoration and environmental funds” that provide guidance for determining the recognition and measurement for the contribution to funds established to finance decommissioning that have the following features: (a) the assets are held and administered by a separate legal entity; and (b) contributor’s right to access the assets of the fund is restricted.
The contributor recognizes its obligation to pay separately decommissioning costs as a liability and its interest in the fund. In the case that the interest means having control, having joint control or significant influence over the fund, the entity contributor must recognize the interest in the fund as an investment in a subsidiary, associate or joint venture.
The adoption of these principles did not generate a material effect.

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Use of accounting estimates
The preparation of these consolidated financial statements requires Management to apply accounting estimates that are based on complex or subjective judgments, estimates based on past experience and assumptions determined to be reasonable and realistic considering the information available at the date of the estimate. The application of these estimates and assumptions affects the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the balance sheet date and the reported amounts of income and expenses during the reporting period. Actual results may differ from these estimates given the uncertainty surrounding the assumptions and conditions upon which the estimates are based. Summarized below are the critical accounting estimates that require the more subjective judgment of our management. Such assumptions or estimates regard the effects of matters that are inherently uncertain and for which changes in conditions may significantly affect future results.

Oil and gas activities
Engineering estimates of the Company’s oil and gas reserves are inherently uncertain. Proved reserves are the estimated volumes of crude oil, natural gas and gas condensates, liquids and associated substances which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Although there are authoritative guidelines regarding the engineering criteria that must be met before estimated oil and gas reserves can be designated as “proved”, the accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment.
Field reserves will only be categorized as proved when all the criteria for attribution of proved status have been met. At this stage, all booked reserves will be categorized as proved undeveloped. Volumes will subsequently be recategorized from proved undeveloped to proved developed as a consequence of development activity. The first proved developed bookings will occur at the point of first oil or gas production. Major development projects typically take one to four years from the time of initial booking to the start of production. Adjustments may be made to booked reserves due to production, reservoir performance, commercial factors, acquisition and divestment activity and additional reservoir development activity. In particular, changes in oil and natural gas prices could impact the amount of Eni’s proved reserves as regards the initial estimate and, in the case of Production Sharing Agreements and buy-back contracts, the share of production and reserves to which Eni is entitled. Accordingly, the estimated reserves could be materially different from the quantities of oil and natural gas that ultimately will be recovered.
Oil and natural gas reserves have a direct impact on certain amounts reported in the Financial Statements. Estimated proved reserves are used in determining depreciation and depletion expenses and impairment expense. Depreciation rates on oil and gas assets using the UOP basis are determined from the ratio between the amount of hydrocarbons extracted in the quarter and proved developed reserves existing at the end of the quarter increased by the amounts extracted during the quarter. Assuming all other variables are held constant, an increase in estimated proved developed reserves decreases depreciation, depletion and amortization expense. On the contrary, a decrease in estimated proved developed reserves increases depreciation, depletion and amortization expense. In addition, estimated proved reserves are used to calculate future cash flows from oil and gas properties, which serve as an indicator in determining whether a property impairment is to be carried out or not. The larger the volumes of estimated reserves, the less likely the property is impaired.

Impairment of Assets
Eni assesses its tangible and intangible assets, including goodwill, for possible impairment if there are events or changes in circumstances that indicate that the carrying values of the assets are not recoverable. Such indicators include changes in the Group’s business plans, changes in commodity prices leading to unprofitable performance and, for oil and gas properties, significant downward revisions of estimated proved reserve quantities. Determination as to whether and how much an asset is impaired involves management estimates on highly uncertain matters such as future commodity prices, the effects of inflation and technology improvements on operating expenses, production profiles and the outlook for global or regional market supply and demand conditions for crude oil, natural gas, commodity chemicals and refined products.
The amount of an impairment loss is determined by comparing the book value of an asset with its recoverable amount. The recoverable amount is the greater of fair value net of disposal costs and value in use. The estimated value in use is based on the present values of expected future cash flows net of disposal costs. The expected future cash flows used for impairment reviews are based on judgmental assessments of future production volumes, prices and costs, considering available information at the date of review and are discounted by using a rate related to the activity involved.

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For oil and natural gas properties, the expected future cash flows are estimated based on developed and non-developed proved reserves including, among other elements, production taxes and the costs to be incurred for the reserves yet to be developed. The estimated future level of production is based on assumptions on: future commodity prices, lifting and development costs, field decline rates, market demand and supply, economic regulatory climates and other factors.
Goodwill and other intangible assets with indefinite useful life are not amortized but they are checked at least annually to determine whether their carrying amount is recoverable and in any case, when trigger events arise that would lead the entity to assume the value of an asset is impaired. In particular, goodwill impairment is based on the determination of the fair value of each cash generating unit to which goodwill can be attributed on a reasonable and consistent basis. A cash generating unit is the smallest aggregate on which the company, directly or indirectly, evaluates the return on the capital expenditure. If the fair value of a cash generating unit is lower than the carrying amount, goodwill attributed to that cash generating unit is impaired up to that difference; if the carrying amount of goodwill is less than the amount of impairment, assets of the cash generating unit are impaired on a pro-rata basis for the residual difference.

Asset Retirement Obligations
Obligations related to the removal of tangible equipment and the restoration of land or seabeds require significant estimates in calculating the amount of the obligation and determining the amount required to be recorded in the Consolidated Financial Statements. Estimating future asset removal costs is difficult and requires management to make estimates and judgments due to the fact that most removal obligations will come to term many years into the future and contracts and regulations are often unclear as to what constitutes removal. Asset removal technologies and costs are constantly changing, as well as political, environmental, safety and public relations considerations. The subjectivity of these estimates is also increased by the accounting method used that requires entities to record the fair value of a liability for an asset retirement obligations in the period when it is incurred (typically, at the time, the asset is installed at the production location). When liabilities are initially recorded, the related fixed assets are increased by an equal corresponding amount. The liabilities are increased with the passage of time (interest accretion) and any change of the estimates following the modification of future cash flows and discount rate is adopted. The recognized asset retirement obligations are based upon future retirement cost estimates and incorporate many assumptions such as: expected recoverable quantities of crude oil and natural gas, abandonment time, future inflation rates and the risk-free rate of interest adjusted for the Company’s credit costs.

Business Combinations
Accounting for the acquisition of a business requires the allocation of the purchase price to most assets and liabilities acquired at fair value. Any positive residual difference is recognized as “Goodwill”. Negative residual differences are charged against the profit and loss account. Management uses all available information to make these fair value determinations and, for major business acquisitions, typically engages an independent appraisal firm to assist in the fair value determination of the acquired assets and liabilities.

Environmental Liabilities
Together with other companies in the industries in which it operates, Eni is subject to numerous EU, national, regional and local environmental laws and regulations concerning its oil and gas operations, productions and other activities, including legislation that implements international conventions or protocols. Environmental costs are recognized when it becomes probable that a liability has been incurred and the amount can be reasonably estimated.
Although management, considering the actions already taken, insurance policies to cover environmental risks and provision for risks accrued, does not expect any material adverse effect on Eni’s consolidated results of operations and financial position as a result of such laws and regulations, there can be no assurance that there will not be a material adverse impact on Eni’s consolidated results of operations and financial position due to: (i) the possibility of a yet unknown contamination; (ii) the results of the ongoing surveys and other possible effects of statements required by Decree No. 471/1999 of the Ministry of Environment concerning the remediation of contaminated sites; (iii) the possible effect of future environmental legislation and rules; (iv) the effect of possible technological changes relating to future remediation; and (v) the possibility of litigation and the difficulty of determining Eni’s liability, if any, as against other potentially responsible parties with respect to such litigation and the possible insurance recoveries.

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Employees benefits
Defined benefit plans and other long term benefits are evaluated with reference to uncertain events and based upon actuarial assumptions including among others discount rates, expected rates of return on plan assets, expected rates of salary increases, medical cost trend rates, estimated retirement dates, mortality rates.
The significant assumptions used to account for pensions and other post-retirement benefits are determined as follows: (i) discount and inflation rates reflect the rates at which benefits could be effectively settled, taking into account the duration of the obligation. Indications used in selecting the discount rate include rates of annuity contracts and rates of return on high quality fixed-income investments (such as government bonds). The inflation rates reflect market conditions observed country by country; (ii) the future salary levels of the individual employees are determined including an estimate of future changes attributed to general price levels (consistent with inflation rate assumptions), productivity, seniority and promotion; (iii) healthcare cost trend assumptions reflect an estimate of the actual future changes in the cost of the healthcare related benefits provided to the plan participants and are based on past and current healthcare cost trends including healthcare inflation, changes in healthcare utilization and changes in health status of the participants; (iv) demographic assumptions such as mortality, disability and turnover reflect the best estimate of these future events for the individual employees involved, based principally on available actuarial data; (v) determination of expected rates of return on assets is made through compound averaging. For each plan, the distribution of investments among bonds, equities and cash and their specific average expected rate of return is taken into account. Differences between expected and actual costs and between the expected return and the actual return on plan assets routinely occur and are called actuarial gains and losses.
Eni applies the corridor method to amortize its actuarial losses and gains. This method amortizes on a pro-rata basis the net cumulative actuarial gains and losses, unrecognized at the end of the previous reporting period, that exceed 10% of the greater of (i) the present value of the defined benefit obligation and (ii) the fair value of plan assets, over the average expected remaining working lives of the employees participating in the plan.
Additionally, obligations for other long term benefits are determined by adopting actuarial assumptions; the effect of changes in actuarial assumptions or a change in the characteristics of the benefit are taken to profit or loss in their entirety.

Contingencies
In addition to accruing the estimated costs for environmental liabilities, asset retirement obligations and employees benefits, Eni accrues for all contingencies that are both probable and estimable. These other contingencies are primarily related to litigation and tax issues. Determining appropriate amounts for accrual is a complex estimation process that includes subjective judgments.

Revenue recognition in the Engineering & Construction segment
Revenue recognition in the Engineering & Construction business segment is based on the stage of completion of a contract as measured on the cost-to-cost basis applied to contractual revenues. Use of the stage of completion method requires estimates of future gross profit on a contract by contract basis. The future gross profit represents the profit remaining after deducting costs attributable to the contract from revenues provided for in the contract. The estimate of future gross profit is based on a complex estimation process, that includes identification of risks related to geographical region, market conditions in that region and any assessment that it is necessary to estimate with sufficient precision the total future costs as well as the expected timetable. Requests of additional incomes, deriving from a change in the scope of the work, are included in the total amount of revenues when it is probable that the customer will approve the variation and the related amount; claims deriving for instance from additional costs incurred for reasons attributable to the client are included in the total amount of revenues when it is probable that the counterpart will accept them.



Recent accounting principles

With Regulation No. 108/2006 issued on January 11, 2006 the European Commission approved IFRS 7 “Financial instruments: disclosures”. IFRS 7 establishes the disclosures to be provided regarding financial instruments and the exposure and management of financial risks. The requirements of IFRS 7 include some disclosures currently required by IAS 32 “Financial instruments: exposures and additional disclosures”. IFRS 7 went into effect on January 1, 2007.
Eni is presently analyzing this statements and, at the moment, cannot determine if adoption of this tandard will have a significant effect on Eni’s Consolidated Financial Statements.

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Notes to the Consolidated Financial Statements

Current activities

1 Cash and cash equivalent
Cash and cash equivalent of euro 3,985 million (euro 1,333 million at December 31, 2005) include financing receivables originally due within 90 days for euro 240 million (euro 122 million at December 31, 2005) and consist of deposits with financial institutions with a notice of over 48 hours.


2 Other financial assets held for trading or available for sale
Other financial assets held for trading or available for sale of euro 972 million (euro 1,368 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Securities held for operating purposes:          
- listed Italian treasury bonds   361   329  
- listed securities issued by Italian and foreign merchant banks   92   80  
- non-quoted securities   12   11  
    465   420  
Securities held for non-operating purposes:          
- listed Italian treasury bonds   727   508  
- listed securities issued by Italian and foreign merchant banks   151   40  
- non-quoted securities   25   4  
    903   552  
    1,368   972  
   
 
 

Securities of euro 972 million (euro 1,368 million at December 31, 2005) are available for sale. The decrease of euro 396 million primarily concerns sales made by the financial company Enifin SpA (euro 303 million) and the effect of the sale of Sofid Sim SpA (euro 90 million). At December 31, 2005 and December 31, 2006 Eni did not own financial assets held for trading.
The effects of the valuation at fair value of securities consist of the following:

(million euro)   Dec. 31, 2005   Increase   Realization to the profit and loss account   Dec. 31, 2006
   
 
 
 
Fair value   27     2     (21 )   8  
Deferred tax liabilities   8           (6 )   2  
Other reserves of shareholders’ equity   19     2     (15 )   6  
   

 

 

 

The realization of the fair value to the profit and loss account of euro 21 million and of the related deferred tax liabilities of euro 6 million concern the expiring of securities of Padana Assicurazioni SpA. Securities held for operating purposes of euro 420 million (euro 465 million at December 31, 2005) concern securities covering technical reserves of Padana Assicurazioni SpA for euro 417 million (euro 453 million at December 31, 2005).

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3 Trade and other receivables
Trade and other receivables of euro 18,799 million (euro 17,902 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Trade receivables   14,101   15,230
Financing receivables:        
- for operating purposes - short-term   480   242
- for operating purposes - current portion of long term receivables       4
- for non-operating purposes   12   143
    492   389
Other receivables        
- from disposals   60   100
- other   3,249   3,080
    3,309   3,180
    17,902   18,799
   
 

Receivables are recorded net of the allowance for impairment losses of euro 874 million (euro 891 million at December 31, 2005):

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
Trade receivables   643     129     (77 )   (108 )   587  
Other receivables   248     78     (7 )   (32 )   287  
    891     207     (84 )   (140 )   874  
   

 

 

 

 

Trade receivables of euro 15,230 million increased by euro 1,129 million. This increase primarily relates to the Exploration & Production segment (euro 1,391 million) and the Engineering & Construction segment (euro 832 million); such increase was partially offset by the decrease of the Refining & Marketing segment (euro 302 million) and the Gas & Power segment (euro 292 million) and includes the exchange rate differences due to the translation of financial statements prepared in currencies other than the euro for euro 263 million. Trade receivables include advances paid as a guarantee on contract work in progress for euro 70 million (euro 101 million at December 31, 2005).
Financing receivables made for operating purposes of euro 246 million (euro 480 million at December 31, 2005) concern concessions, primarily, to unconsolidated subsidiaries, joint ventures and affiliates. The decrease of euro 234 million primarily concern the repayment of funding given to Trans Austria Gasleitung GmbH (euro 292 million).
Other receivables of euro 3,180 million (euro 3,309 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Accounts receivable from:        
- joint venture operators in exploration and production   1,123   1,376
- Italian governmental entities   228   266
- insurance companies   539   223
    1,890   1,865
Receivables relating to factoring operations   324   191
Prepayments for services   259   440
Other receivables   836   684
    3,309   3,180
   
 

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Receivables relating to factoring operations for euro 191 million (euro 324 million at December 31, 2005) relate to Serfactoring SpA and essentially concern advances for factoring operations with recourse and receivables for factoring operations without recourse.
Receivables with related parties are described in Note 33 - Transactions with related parties.


4 Inventories
Inventories of euro 4,752 million (euro 3,563 million at December 31, 2005) consist of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 

(million euro)

 

Crude oil, gas and petroleum products

 

Chemical products

 

Work in progress long-term contracts

 

Other

 

Total

 

Crude oil, gas and petroleum products

 

Chemical products

 

Work in progress long-term contracts

 

Other

 

Total

   
 
 
 
 
 
 
 
 
 
Raw and auxiliary materials and consumables   210   217       645   1,072   436   258       682   1,376
Products being processed and semi finished products   59   18       1   78   43   20       8   71
Work in progress long-term contracts           418       418           353       353
Finished products and goods   1,222   572       20   1,814   2,063   536       62   2,661
Advances           181       181   1       287   3   291
    1,491   807   599   666   3,563   2,543   814   640   755   4,752
   
 
 
 
 
 
 
 
 
 

Inventories are net of the valuation allowance of euro 92 million (euro 93 million at December 31, 2005):

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
          93     19     (14 )   (6 )   92  
   
 
 
 
 

Work in progress long-term contracts of euro 353 million (euro 418 million at December 31, 2005) are net of the payments received corresponding to contractual amount of the work performed of euro 5,237 million (euro 5,180 million at December 31, 2005).


5 Current tax assets
Current tax assets of euro 658 million (euro 697 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Italian tax   422   394
Foreign tax   275   264
    697   658
   
 

Current tax assets of euro 658 million (euro 697 million at December 31, 2005) concern value added tax credits for euro 303 million (euro 406 million at December 31, 2005), income tax receivables of euro 116 million (euro 127 million at December 31, 2005) and excise taxes customs duties natural gas and customs expenses for euro 86 million (euro 60 million at December 31, 2005).

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6 Other assets
Other assets of euro 855 million (euro 369 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Fair value of non-hedging derivatives   117   569
Fair value of cash flow hedge derivatives   32   37
Fair value of fair value hedge derivatives       1
Other assets   220   248
    369   855
   
 

Fair value of non hedging derivative contracts of euro 569 million (euro 117 million at December 31, 2005) consists of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 
(million euro)   Fair Value   Commitments   Fair Value   Commitments
   
 
 
 
Non-hedging derivatives on exchange rate                
Interest Currency Swap   58   1,277   137   1,400
Currency swap   15   2,378   46   5,502
Other       26       42
    73   3,681   183   6,944
Non-hedging derivatives on interest rate                
Interest Rate Swap   14   1,281   66   3,393
    14   1,281   66   3,393
Non-hedging derivatives on commodities                
Over the counter   21   394   35   262
Other   9   11   285   851
    30   405   320   1,113
    117   5,367   569   11,450
   
 
 
 

Fair value of cash flow hedge derivative contracts of euro 37 million concerns commitments for euro 421 million and relates to future sales of crude oil of the Exploration & Production segment.
Cash flow hedge derivative contracts at December 31, 2005 relating to the purchase of electricity expired during 2006 and the effect was charged to the profit and loss account.
Information about the risk of hedged items and to Eni's hedging policy is included in Note 25 - Guarantees, commitments and risks - Management of risks.

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Non-current activities

7 Property, plant and equipment
Tangible assets of euro 44,312 million (euro 45,013 million at December 31, 2005) consist of the following:

(million euro)   Net value at the beginning of the year   Investments   Depreciations   Impairments   Exchange rate differences   Other changes   Net value at the end of the year   Gross value at the end of the year   Provisions for amortization and impairments
   
 
 
 
 
 
 
 
 
Dec. 31, 2005                                                      
Land   197     5           (4 )         175     373     421     48  
Buildings   1,578     41     (108 )   (8 )   12     (62 )   1,453     3,152     1,699  
Plant and machinery   30,849     2,443     (4,240 )   (192 )   1,827     5,881     36,568     77,806     41,238  
Industrial and commercial equipment   422     113     (126 )         10     (47 )   372     1,623     1,251  
Other assets   329     65     (102 )         12     14     318     1,182     864  
Tangible assets in progress and advances   7,211     3,891           (60 )   590     (5,703 )   5,929     6,526     597  
    40,586     6,558     (4,576 )   (264 )   2,451     258     45,013     90,710     45,697  
Dec. 31, 2006                                                      
Land   373     16           (3 )         57     443     483     40  
Buildings   1,453     81     (113 )   (12 )   (5 )   38     1,442     3,236     1,794  
Plant and machinery   36,568     1,858     (4,510 )   (197 )   (1,586 )   3,240     35,373     79,873     44,500  
Industrial and commercial equipment   372     130     (120 )         (6 )   50     426     1,659     1,233  
Other assets   318     82     (78 )   (1 )   (9 )   16     328     1,382     1,054  
Tangible assets in progress and advances   5,929     3,971           (18 )   (364 )   (3,218 )   6,300     6,822     522  
    45,013     6,138     (4,821 )   (231 )   (1,970 )   183     44,312     93,455     49,143  
   

 

 

 

 

 

 

 

 

Capital expenditures of euro 6,138 million (euro 6,558 million at December 31, 2005) primarily relate to the Exploration & Production segment (euro 3,678 million), the Gas & Power segment (euro 1,051 million), the Refining & Marketing segment (euro 632 million) and to the Engineering & Construction segment (euro 584 million). Capital expenditures include financial expenses for euro 116 million (euro 159 million at December 31, 2005) and are essentially related to the Exploration & Production segment (euro 70 million), the Gas & Power segment (euro 24 million) and the Refining & Marketing segment (euro 19 million). The interest rate used for the capitalization of financial expense was between 3.3% and 5.4% (2.2% and 6.1% at December 31, 2005).
The depreciation rates used are as follows:

(%)                  
Buildings        

2

 

-

10

 
Plant and machinery        

2

 

-

10

 
Industrial and commercial equipment        

4

 

-

33

 
Other assets        

6

 

-

33

 

Exchange rate differences due to the translation of financial statements prepared in currencies other than the euro of euro 1,970 million relate to companies whose functional currency is the U.S. dollar (euro 1,913 million).
Impairments of euro 231 million concern primarily mineral assets of the Exploration & Production segment (euro 129 million) and petrochemical assets of the Petrochemical segment (euro 65 million) and of Syndial SpA (euro 22 million). The recoverable amount considered in determining the impairment was calculated by discounting the future cash flows using discount rates included between 7.6% and 11.2%.
Other changes of euro 183 million primarily concern the initial recognition and revision of the estimate of costs for dismantling and restoration of sites for euro 1,157 million essentially related to the Exploration & Production segment (euro 1,153 million).

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This increase was partially offset by the reclassification to "Other assets" of tangible assets related to the service contract governing mineral activities in the Dación area owned by the Venezuelan controlled branch Eni Dación BV for euro 629 million, the sale of tangible assets for euro 197 million, of which euro 158 million relating to mineral assets of the Exploration & Production segment and the change in scope of consolidation of euro 66 million essentially following the sale of Fiorentina Gas SpA (euro 157 million) and the acquisition of Siciliana Gas SpA (euro 91 million).
The gross carrying amount of fully depreciated property, plant and equipment that is still in use amount to euro 12,187 million and primarily concerns refineries and storage sites of the Refining & Marketing segment (euro 4,507 million), the gas transportation network of Snam Rete Gas SpA (euro 3,486 million), and petrochemical plants of the Petrochemical segment (euro 1,911 million) and Syndial SpA (euro 1,682 million).
At December 31, 2005, tangible assets were pledged for euro 54 million primarily as collateral on debt incurred by Eni (euro 475 million at December 31, 2005). The decrease of euro 421 million essentially concerns the extinguishment of guarantees given (euro 418 million).
Government grants recorded as decrease of property, plant and equipment amount to euro 1,067 million (euro 965 million at December 31, 2005).
Assets acquired under financial lease amount to euro 89 million and concern for euro 39 million FPSO ships used by the Exploration & Production segment as support for oil production and treatment activities and for euro 36 million a drilling platform of the Engineering & Construction segment.

Property, plant and equipment by segment

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Property, plant and equipment, gross:            
- Exploration & Production   49,129     49,002  
- Gas & Power   21,517     22,277  
- Refining & Marketing   9,420     11,273  
- Petrochemical   4,402     4,380  
- Engineering & Construction   3,878     4,363  
- Other activities   1,999     1,967  
- Corporate and financial companies   453     321  
- Elimination of intra-group profits   (88 )   (128 )
    90,710     93,455  
Accumulated depreciation, amortization and writedowns:            
- Exploration & Production   24,644     26,000  
- Gas & Power   7,757     8,210  
- Refining & Marketing   5,864     7,482  
- Petrochemical   3,263     3,308  
- Engineering & Construction   2,031     2,138  
- Other activities   1,882     1,874  
- Corporate and financial companies   260     145  
- Elimination of intra-group profits   (4 )   (14 )
    45,697     49,143  
Property, plant and equipment, net:            
- Exploration & Production   24,485     23,002  
- Gas & Power   13,760     14,067  
- Refining & Marketing   3,556     3,791  
- Petrochemical   1,139     1,072  
- Engineering & Construction   1,847     2,225  
- Other activities   117     93  
- Corporate and financial companies   193     176  
- Elimination of intra-group profits   (84 )   (114 )
    45,013     44,312  
   

 

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8 Other assets
Other assets of euro 629 million concern the tangible assets related to the service contract governing mineral activities in the Dación area and owned by the Venezuelan controlled branch Eni Dación BV. Additional information is included in Note 25 - Guarantees, commitments and risks - Other commitments and risks.

9 Inventories - Compulsory stock
Inventories - compulsory stocks of euro 1,827 million (euro 2,194 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Crude oil and petroleum products  

2,037

   

1,670

 
Natural gas  

157

   

157

 
   

2,194

   

1,827

 

Compulsory stocks, are primarily held by Italian companies (euro 2,057 and euro 1,688 million at December 31, 2005 and at December 31, 2006, respectively) and represent certain minimum quantities required by Italian law.


10 Intangible assets
Intangible assets of euro 3,753 million (euro 3,194 million at December 31, 2005) consist of the following:

(million euro)  

Net value at the beginning of the year

 

Investments

 

Amortization

 

Other changes

 

Net value at the end of the year

 

Gross value at the end of the year

 

Provisions for amortization
and writedowns

   
 
 
 
 
 
 
Dec. 31, 2005                                          
Intangible assets with a definite life                                          
- Costs for research of mineral resources   107     699     (683 )   41     164     1,059     895  
- Industrial patent rights and intellectual property rights   174     37     (122 )   48     137     1,056     919  
- Concessions, licenses, trademarks and similar items   816     31     (101 )         746     2,205     1,459  
- Intangible assets in progress and advances   59     74           (57 )   76     81     5  
- Other intangible assets   224     13     (30 )   (50 )   157     470     313  
    1,380     854     (936 )   (18 )   1,280     4,871     3,591  
Intangible assets with a indefinite life                                          
- Goodwill   1,933     2           (21 )   1,914              
    3,313     856     (936 )   (39 )   3,194              
Dec. 31, 2006                                          
Intangible assets with a definite life                                          
- Costs for research of mineral resources   164     1,337     (1,102 )   10     409     1,290     881  
- Industrial patent rights and intellectual property rights   137     31     (97 )   41     112     1,113     1,001  
- Concessions, licenses, trademarks and similar items   746     168     (110 )   52     856     2,417     1,561  
- Intangible assets in progress and advances   76     146           (71 )   151     156     5  
- Other intangible assets   157     13     (26 )   (3 )   141     457     316  
    1,280     1,695     (1,335 )   29     1,669     5,433     3,764  
Intangible assets with a indefinite life                                          
- Goodwill   1,914                 170     2,084              
    3,194     1,695     (1,335 )   199     3,753              
   

 

 

 

 

 

 

Costs for research of mineral resources for euro 409 million concern the purchase of mineral rights (euro 404 million). This item also includes exploration expenditures amortized in full in the period incurred for euro 1,028 million (euro 565 million at December 31, 2005).

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Concessions, licenses, trademarks and similar items for euro 856 million primarily concern the transport rights for natural gas imported from Algeria (euro 572 million) and concessions for mineral exploration (euro 223 million). Other intangible assets with a definite life of euro 141 million include royalties for the use of licenses by Polimeri Europa SpA (euro 81 million) and the estimated expenditures for social projects to be incurred following contractual commitments with the Basilicata Region related to mineral development programs in Val d’Agri (euro 26 million).
The depreciation rates used are as follows:

(%)                  
Costs for research and development        

10

 

-

33

 
Industrial patent rights and intellectual property rights        

20

 

-

33

 
Concessions, licenses, trademarks and similar items        

7

 

-

33

 
Other intangible assets        

4

 

-

25

 

The gross carrying amount of fully depreciated intangible assets still in use amount to euro 767 million.
Other changes of intangible assets with a definite life of euro 29 million include negative exchange rate differences due to the translation of financial statements prepared in currencies other than the euro of euro 28 million.
Goodwill for euro 2,084 million concerns essentially the Engineering & Construction segment (euro 828 million, of which euro 805 million relates to the purchase of Bouygues Offshore SA, now Saipem SA), the Gas & Power segment (euro 982 million, of which euro 757 million relates to the public offering of Italgas SpA shares in 2003), the Exploration & Production segment (euro 225 million, of which euro 220 million relates to the purchase of Lasmo Plc, now Eni Lasmo Plc) and the Refining & Marketing segment (euro 46 million).
In order to determine the recoverable amount, goodwill related to the acquisition of Bouygues Offshore SA and Italgas SpA has been allocated to the following cash generating units:

(million euro)  

Dec. 31, 2006

   
Bouygues Offshore SA      
Offshore constructions  

403

 
Onshore constructions  

165

 
LNG  

159

 
MMO - Maintenance Modification and Operation  

78

 
   

805

 
Italgas SpA      
Domestic gas market  

706

 
Foreign gas market  

51

 
   

757

 
   

The recoverable amount of cash generating units is determined based on expected cash flows estimated using the market assumptions of Eni’s 2007-2010 Strategic Plan and discounted at rates included between 4.7% and 14.3%. For the years not included in the strategic market assumptions, Eni has used an incremental rate included between 0% and 2%. Key assumptions are based on past experience and take into account the current level of interest rates.
Other changes related to goodwill of euro 170 million concern the allocation to goodwill of the difference between the price paid by Snam Rete Gas SpA and Saipem SpA for the purchase of treasury shares and the corresponding portion of shareholders’ equity acquired following the increase of Eni’s interest (euro 171 million) and the change in scope of consolidation related to the acquisition of 50% of Siciliana Gas SpA (euro 23 million). Such increase was partially offset by the decrease in the impairment of goodwill allocated to Tigaz Zrt following its acquisition by Italgas SpA (euro 46 million). The impairment of goodwill allocated to Tigaz Zrt was made following the application of the new Hungarian tariff regime, in force from 2006, and was determined on the basis of the new estimate of future cash flows, discounted by using a rate of 6.3%.

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11 Investments

Investments accounted for using the equity method
Investments accounted for using the equity method of euro 3,886 million (euro 3,890 million at December 31, 2005) consist of the following:

(million euro)   Value at the beginning of the year   Acquisitions and subscriptions   Gain from the valuation of investments accounted for using the equity method   Loss from the valuation of investments accounted for using the equity method   Deduction for dividends   Exchange rate differences   Other changes   Value at the end of the year
   
 
 
 
 
 
 
 
Dec. 31, 2005                                                
Investments in unconsolidated subsidiaries   109     30     6     (2 )   (3 )   10     (4 )   146  
Investments in joint ventures   1,946     12     375     (27 )   (202 )   98     182     2,384  
Investments in affiliates   1,101     6     389     (4 )   (96 )   34     (70 )   1,360  
    3,156     48     770     (33 )   (301 )   142     108     3,890  
Dec. 31, 2006                                                
Investments in unconsolidated subsidiaries   146     4     15     (8 )   (8 )   (6 )   1     144  
Investments in joint ventures   2,322     33     516     (26 )   (302 )   (79 )   42     2,506  
Investments in affiliates   1,422     1     356     (2 )   (440 )   (31 )   (70 )   1,236  
    3,890     38     887     (36 )   (750 )   (116 )   (27 )   3,886  
   

 

 

 

 

 

 

 

Acquisitions and subscriptions for euro 38 million concern mainly the subscriptions of capital increase of Enirepsa Gas Ltd (euro 23 million) and Saipem Triune Engineering Private Ltd (euro 8 million). Gains from the valuation of investments using the equity method of euro 887 million primarily relate to Galp Energia SGPS SA (euro 250 million), Unión Fenosa Gas SA (euro 181 million), EnBw Eni Verwaltungsgesellschaft mbH (euro 64 million), Blue Stream Pipeline Co BV (euro 44 million), Supermetanol CA (euro 43 million), United Gas Derivatives Co (euro 39 million), Trans Austria Gasleitung GmbH (euro 36 million), Lipardiz-Construção de Estruturas Maritimas Lda (euro 31 million) and Gaztransport et Technigaz SAS (euro 28 million).
Losses from the valuation of investments using the equity method of euro 36 million primarily relate to Enirepsa Ltd (euro 21 million). Deduction following the distribution of dividends of euro 750 million primarily relates to Galp Energia SGPS SA (euro 364 million), Unión Fenosa Gas SA (euro 128 million), Trans Austria Gasleitung GmbH (euro 43 million), United Gas Derivatives Co (euro 33 million) and Supermetanol CA (euro 32 million).
Other changes of euro 27 million concern the inclusion in consolidation of Siciliana Gas SpA following the acquisition of the remaining 50% interest from ESPI - Ente Siciliano per la Promozione Industriale (in liquidation) (euro 60 million) and, as an increase, the contribution of Fiorentina Gas SpA to Toscana Energia SpA (euro 67 million).

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The net carrying value of euro 3,886 million (euro 3,890 million at December 31, 2005) concerns the following companies:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
   

Net value

 

Eni’s interest %

 

Net value

 

Eni’s interest %

   
 
 
 
Unconsolidated subsidiaries:                
- Eni Btc Ltd   55   100.00   46   100.00
- Others (*)   91       98    
    146       144    
Joint ventures:                
- Unión Fenosa Gas SA   459   50.00   503   50.00
- Blue Stream Pipeline Co BV   280   50.00   293   50.00
- EnBW - Eni Verwaltungsgesellschaft mbH   168   50.00   234   50.00
- Raffineria di Milazzo ScpA   172   50.00   171   50.00
- Azienda Energia e Servizi Torino SpA   165   49.00   165   49.00
- Eteria Parohis Aeriou Thessalonikis AE   152   49.00   157   49.00
- Toscana Energia SpA           111   48.72
- Super Octanos CA   113   49.00   97   49.00
- Lipardiz-Construção de Estruturas Maritimas Lda   66   50.00   97   50.00
- Supermetanol CA   88   34.51   90   34.51
- Trans Austria Gasleitung GmbH   88   89.00   81   89.00
- Haldor Topsøe AS   62   50.00   71   50.00
- Unimar Llc   84   50.00   70   50.00
- FPSO Mystras - Produção de Petroleo Lda   73   50.00   63   50.00
- Transmediterranean Pipeline Co Ltd   63   50.00   50   50.00
- Eteria Parohis Aeriou Thessalias AE   39   49.00   46   49.00
- Saibos Akogep Snc   38   70.00   38   70.00
- Transitgas AG   32   46.00   31   46.00
- CMS&A Wll   31   20.00   27   20.00
- Siciliana Gas SpA   60   50.00        
- Toscana Gas SpA   55   46.10        
- Others (*)   96       111    
    2,384       2,506    
Affiliates:                
- Galp Energia SGPS SA   896   33.34   782   33.34
- United Gas Derivatives Co   128   33.33   117   33.33
- Fertilizantes Nitrogenados de Oriente CEC   92   20.00   88   20.00
- Acam Gas SpA   45   49.00   45   49.00
- Distribuidora de Gas del Centro SA   41   31.35   37   31.35
- Gaztransport et Technigaz SAS   20   30.00   29   30.00
- Others (*)   138       138    
    1,360       1,236    
    3,890       3,886    
   
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 25 million.

The net value of investments in unconsolidated subsidiaries, joint ventures and affiliates includes the differences between purchase price and Eni’s equity in investments of euro 576 million. Such differences relate to Unión Fenosa Gas SA (euro 195 million), EnBW Eni Verwaltungsgesellschaft mbH (euro 178 million), Galp Energia SGPS SA (euro 107 million) and Azienda Energia e Servizi Torino SpA (euro 69 million).
Provisions for losses related to investments accounted for using the equity method of euro 154 million, included in the provisions for contingencies, relate primarily to Polimeri Europa Elastomères France SA (euro 50 million), Charville - Consultores e Serviços Lda (euro 37 million), Industria Siciliana Acido Fosforico - ISAF (in liquidation) (euro 31 million) and Geopromtrans Llc (euro 19 million).

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Other investments
Other investments of euro 360 million (euro 421 million at December 31, 2005) consist of the following:

(million euro)   Net value at the beginning of the year   Acquisition and subscriptions   Exchange rate differences   Other changes   Net value at the end of the year   Gross value at the end of the year   Accumulated impairment charges
   
 
 
 
 
 
 
Dec. 31, 2005                                          
Investments in unconsolidated subsidiaries   78     1           (38 )   41     68     27  
Investments in affiliates   107                 (98 )   9     9        
Other investments   344     23     41     (37 )   371     375     4  
    529     24     41     (173 )   421     452     31  
Dec. 31, 2006                                          
Investments in unconsolidated subsidiaries   41                 (20 )   21     49     28  
Investments in affiliates   9                       9     10     1  
Other investments   371     4     (31 )   (14 )   330     332     2  
    421     4     (31 )   (34 )   360     391     31  
   

 

 

 

 

 

 

Investments in unconsolidated subsidiaries and affiliates are valued at cost net of impairment losses. Other investments are essentially valued at cost adjusted for impairment losses, due to the fact that the fair value cannot be reliably determined.
The net carrying amount of Other investments of euro 360 million (euro 421 million at December 31, 2005) concerns the following companies:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
   

Net value

 

Eni’s interest %

 

Net value

 

Eni’s interest %

   
 
 
 
Unconsolidated subsidiaries (*)   41       21    
Affiliates   9       9    
Other investments:                
- Darwin LNG Pty Ltd   126   12.04   108   12.04
- Nigeria LNG Ltd   100   10.40   90   10.40
- Ceska Rafinerska AS   35   16.33   31   16.33
- Others (*)   110       101    
    371       330    
    421       360    
   
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 25 million.

Provisions for losses related to Other investments of euro 30 million, included in the provisions for contingencies, relate primarily to Caspian Pipeline Consortium R - Closed Joint Stock Co (euro 27 million).

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Other information about investments
The following are the amounts, according to Eni’s interest, from the last available Financial Statements of unconsolidated subsidiaries, joint ventures and affiliates:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
   

Unconsolidated subsidiaries

 

Joint Ventures

 

Affiliates

 

Unconsolidated subsidiaries

 

Joint Ventures

 

Affiliates

   
 
 
 
 
 
Total assets   1,404     7,423   2,763   1,315   7,906   2,998
Total liabilities   1,263     5,161   1,295   1,182   5,466   1,753
Net sales from operations   63     4,617   1,560   71   5,536   4,905
Operating profit   (1 )   609   176   (1 ) 790   454
Net profit   (2 )   328   371   3   465   351
   

 
 
 
 
 

Total assets and total liabilities relating to unconsolidated companies of euro 1,315 and euro 1,182 million (euro 1,404 and euro 1,263 million at December 31, 2005) concern for euro 900 and euro 900 million (euro 1,004 and euro 1,004 million at December 31, 2005) companies for which consolidation does not produce significant effects.


12 Other financial assets
Other financial receivables of euro 805 million (euro 1,050 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Financial receivables        
- for operating purposes   754   532
- for non-operating purposes   247   252
    1,001   784
Securities        
- for operating purposes   21   21
- for non-operating purposes   28    
    49   21
    1,050   805
   
 

Financial receivables are presented net of the allowance for impairment losses of euro 24 million (euro 25 million at December 31, 2005).
Operating financial receivables of euro 532 million (euro 754 million at December 31, 2005) primarily concern loans made by the Exploration & Production segment (euro 372 million) and Gas & Power segment (euro 81 million). The decrease of euro 222 million concerns exchange rate differences due to the translation of financial statements prepared in currencies other than the euro for euro 61 million. Non-operating financial receivables of euro 252 million (euro 247 million at December 31, 2005) concern a fixed deposit of euro 246 million held by Eni Lasmo Plc as a guarantee of a debt issue (euro 241 million at December 31, 2005).
Receivables in currency other than the euro amount to euro 693 million (euro 845 million at December 31, 2005).
Receivables due beyond five years amount to euro 396 million (euro 625 million at December 31, 2005).
Securities for euro 21 million (euro 49 million at December 31, 2005) are considered held-to-maturity investments and concern securities issued by the Italian Government (euro 22 million at December 31, 2005).
Securities have a maturity within five years.
The fair value evaluation of other financial assets did not have any significant effect.

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13 Deferred tax assets
Deferred tax assets of euro 1,725 million (euro 1,861 million at December 31, 2005) are presented net of deferred tax liabilities for which Eni possesses the legal right of offset for euro 4,028 million (euro 3,347 million at December 31, 2005).

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Exchange rate differences

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
 
   

1,861

   

1,299

   

(1,036

)  

(169

)  

(230

)  

1,725

 
   
 
 
 
 
 

Other changes of euro 230 million primarily concern the offset, for each company, of deferred tax assets with deferred tax liabilities (euro 318 million).
Deferred tax assets are described in Note 22 - Deferred tax liabilities.


14 Other non-current receivables
Other non-current receivables of euro 994 million (euro 995 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Tax receivables from:        
- Italian tax authorities        
  . income tax credits   508   501
  . interest on tax credits   309   322
  . value added tax (VAT)   37   37
  . other   7   13
    861   873
- foreign tax authorities   44   30
    905   903
Other receivables:        
- in relation to disposals   39   2
- others   40   83
    79   85
Other non-current receivables   11   6
    995   994
   
 

 

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Current liabilities

15 Current financial liabilities
Current financial liabilities of euro 3,400 million (euro 4,612 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Banks  

3,894

   

3,178

 
Financial liabilities represented by commercial papers  

60

   

  

 
Other financing institutions  

658

   

222

 
   

4,612

   

3,400

 
   
 

The decrease in current financial liabilities of euro 1,212 million is primarily due to the balance of repayments and new assumptions of liabilities (euro 802 million) and to exchange rate differences related to the translation of financial statements prepared in currencies other than the euro (euro 473 million).
Current financial liabilities by currency are denominated as follows:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Euro  

4,029

   

3,119

 
US Dollar  

323

   

161

 
Other currencies  

260

   

120

 
   

4,612

   

3,400

 
   
 

In fiscal year 2006, the weighted average interest rate of short term debts amounts to 3.9% (2.8% in fiscal year 2005).
At December 31, 2006 Eni has unused committed and uncommitted borrowing facilities amounting respectively to euro 5,896 million and euro 6,523 million, respectively (euro 5,855 million and euro 4,783 million at December 31, 2005). Interest rates of these contracts reflect market conditions and the charges for non-use are not material.


16 Trade and other payables
Trade and other payables of euro 15,995 million (euro 13,095 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Trade payables   8,170   10,528
Advances   1,184   1,362
Other payables:        
- in relation to investments   698   1,166
- others   3,043   2,939
    3,741   4,105
    13,095   15,995
   
 

Trade payables of euro 10,528 million increased by euro 2,358 million. Such increase primarily concerns the Exploration & Production segment (euro 1,353 million), Engineering & Construction segment (euro 424 million), Refining & Marketing segment (euro 262 million) and Gas & Power segment (euro 194 million) and includes exchange rate differences related to the translation of financial statements prepared in currencies other than the euro for euro 181 million.
Advances of euro 1,362 million (euro 1,184 million at December 31, 2005) concern payments received in excess of the value of the work in progress performed for euro 884 million (euro 550 million at December 31, 2005), advances on contract work in progress for euro 197 million (euro 309 million at December 31, 2005) and other advances for euro 281 million (euro 325 million at December 31, 2005). Advances on contract work in progress concern the Engineering & Construction segment.

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Other payables of euro 4,105 million (euro 3,741 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Payables due to:        
- joint venture operators in exploration and production activities   1,264   1,146
- suppliers in relation to investments   951   923
- social security entities   229   339
- employees   314   336
- non-financial governmental entities   313   274
    3,071   3,018
Cautionary deposit   6   2
Other payables   664   1,085
    3,741   4,105
   
 

Payables with related parties are described in Note 33 - Transactions with related parties.

17 Taxes payable
Taxes payable of euro 2,830 million (euro 3,430 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Income taxes payable  

1,742

   

1,640

 
Customs and excise duties  

896

   

683

 
Other  

792

   

507

 
   

3,430

   

2,830

 
   
 

Taxes payable of euro 1,640 million (euro 1,742 million at December 31, 2005) concern Italian companies for euro 158 million and foreign companies for euro 1,482 million (euro 234 million and euro 1,508 million at December 31, 2005, respectively). The decrease of euro 102 million includes exchange rate differences related to the translation of financial statements prepared in currencies other than the euro (euro 70 million).


18 Other current liabilities
Other current liabilities of euro 634 million (euro 613 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Fair value of non-hedging derivatives   378    

395

 
Fair value of cash flow hedge derivatives   5    

40

 
Other liabilities  

230

   

199

 
   

613

   

634

 
   
 

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The fair value of non-hedging derivative contracts of euro 395 million (euro 378 million at December 31, 2005) consists of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 
(million euro)   Fair Value   Commitments   Fair Value   Commitments
   
 
 
 
Non-hedging derivatives on exchange rates                
Currency Swap   139   6,370   11   1,291
Interest Currency Swap   73   2,316   19   257
Other   2   57   2   70
    214   8,743   32   1,618
Non-hedging derivatives on interest rates                
Interest Rate Swap   101   5,145   30   2,122
    101   5,145   30   2,122
Non-hedging derivatives on commodities                
Over the counter   21   323   52   635
Other   42   94   281   930
    63   417   333   1,565
    378   14,305   395   5,305
   
 
 
 

Fair value of cash flow hedge derivatives of euro 40 million concerns commitments for euro 529 million related to future sales of crude oil by the Exploration & Production segment. Cash flow hedge derivatives on exchange rate at December 31, 2005 were closed in 2006 with the effects charged to the profit and loss account.
Information concerning the hedged risks and the hedging policies is shown in Note 25 - Guarantees, commitments and risks - Risk management.

 

Non-current liabilities

19 Long term debt and current portion of long term debt
Long term debt and the current portion of long term debt, including the related expiration dates, are as follows:

(million euro)

  December 31       Long-term maturity
   
     

Type of debt instrument

 

Maturity range

 

2005

 

2006

 

Current maturity 2007

 

2008

 

2009

 

2010

 

2011

 

After

 

Total

   
 
 
 
 
 
 
 
 
 
Banks:                                        
- ordinary loans   2007-2019   2,174   2,298   127   310   448   348   88   977   2,171
- interest rate assigned loans   2007-2013   45   13   4   3   2   2   1   1   9
- other financing   2006   3                                
        2,222   2,311   131   313   450   350   89   978   2,180
Ordinary bonds   2007-2027   5,339   5,097   685   475   127   946   179   2,685   4,412
Other financing institutions   2007-2019   825   891   74   403   26   29   129   230   817
        8,386   8,299   890   1,191   603   1,325   397   3,893   7,409
   
 
 
 
 
 
 
 
 
 

Long term debt including the current portion of long-term debt of euro 8,299 million (euro 8,386 million at December 31, 2005) decreased by euro 87 million. Such decrease is primarily due to the balance of payments and new subscriptions of liabilities of euro 7 million and to the effect of exchange rate differences on the translation of financial statements prepared in currencies other than the euro and exchange rate differences on the alignment to the year end exchange rate of debts denominated in currencies other than the functional currency for a total of euro 124 million.

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Liabilities towards other financing institutions of euro 891 million included euro 56 million of finance lease transactions. The residual debt, represented by the sum of discounted future lease payments applying the effective interest rate, interests and the total of future lease payments, including the related expiration dates, are as follows:

    Maturity range  
   
 
(million euro)   Within 12 months   Between one and five years   After five years   Total
   
 
 
 
Residual debt   14   33   9   56
Interests   7   11   7   25
Undiscounted value of future lease payments   21   44   16   81
   
 
 
 

Eni entered into financing arrangements with the European Investment Bank, relating to a bank debt that requires it to maintain certain financial ratios generally based on Eni’s Consolidated Financial Statements or of a rating not inferior to A- (S&P) and A3 (Moodys). At December 31, 2005 and December 31, 2006, the amount of short and long term debt subject to restrictive covenants was euro 1,258 million and euro 1,131 million, respectively. In addition, Saipem SpA entered into financing arrangements with banks for euro 75 million (euro 275 million at December 31, 2005), that require it to maintain certain financial ratios generally based on Saipem’s Consolidated Financial Statements. Eni and Saipem are in compliance with the covenants contained in these financing arrangements.
Bonds for euro 5,097 million concern bonds issued within the Euro Medium Term Notes Program for a total of euro 4,424 million and other bonds for a total of euro 673 million.
Bonds as of at December 31, 2006, including the issuing entity, the expiration dates and interest rates, by currency, are as follows:

   

Amount

 

Discount on bond issue and accrued expense

 

Total

 

Value

 

Maturity

 

% rate

                   
 
(million euro)                  

from

 

to

 

from

 

to

   
 
 
 
 
 
 
 
Issuing entity                                  
Euro Medium Term Notes:                                  
- Eni SpA   1,500   42     1,542   Euro       2013       4.625
- Eni Coordination Center SA   1,027   19     1,046   British pound   2007   2019   4.875   5.250
- Eni Coordination Center SA   520   5     525   Euro   2007   2015       variable
- Eni SpA   500   16     516   Euro       2010       6.125
- Eni Coordination Center SA   277   5     282   Euro   2008   2024   2.876   5.050
- Eni Coordination Center SA   193   4     197   U.S. dollar   2013   2015   4.450   4.800
- Eni Coordination Center SA   167         167   Japanese yen   2008   2021   0.810   2.320
- Eni Coordination Center SA   103         103   U.S. dollar   2007   2013       variable
- Eni Coordination Center SA   32         32   Swiss franc       2010       2.043
- Eni Coordination Center SA   14         14   Swiss franc       2007       variable
    4,333   91     4,424                    
Other bonds:                                  
- Eni USA Inc   304   3     307   U.S. dollar       2027       7.300
- Eni Lasmo Plc (*)   224   (11 )   213   British pound       2009       10.375
- Eni USA Inc   152   1     153   U.S. dollar       2007       6.750
    680   (7 )   673                    
    5,013   84     5,097                    
   
 

 
 
 
 
 
 
     
(*)   The bond is guaranteed by a fixed deposit recorded under non-current financial assets (euro 246 million).

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Bonds due within 18 months amount to euro 787 million and concern Eni Coordination Center SA (euro 634 million) and Eni USA Inc (euro 153 million). In 2006, Eni issued bonds for euro 219 million through Eni Coordination Center SA.
Long-term debt and the current portion of long term debt, including the weighted average interest rates, by currency, are as follows:

   

Dec. 31, 2005
(million euro)

 

Average rate
(%)

 

Dec. 31, 2006
(million euro)

 

Average rate
(%)

   
 
 
 
Euro   5,344   3.6   5,566   4.0
U.S. dollar   1,709   7.0   1,261   7.8
British pound   1,082   5.3   1,259   5.9
Japanese yen   153   1.4   167   1.4
Swiss franc   98   2.6   46   2.0
    8,386       8,299    
   
 
 
 

At December 31, 2006 Eni has unused committed long term borrowing facilities amounting to euro 520 million (euro 1,070 million at December 31, 2005). Interest rates on these contracts are at market conditions and the charges for non-use are not material.
Fair value of long-term debt, including the current portion of long term debt, amounts to euro 8,415 million (euro 8,732 million at December 31, 2005) and consists of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Ordinary Bonds   5,633   5,239
Banks   2,222   2,311
Other financing institutions   877   865
    8,732   8,415
   
 

The fair value was calculated by discounting the future cash flows using rates between 3.6% and 5.6% (2.8% and 5.0% at December 31, 2005). Financial liabilities for euro 231 million are guaranteed by mortgages and liens on tangible assets of consolidated companies and by pledges on securities and fixed deposits (euro 251 million at December 31, 2005).
Net borrowings, as defined in the "Financial Review" in the "Report of the Directors", consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
   

Current

 

Non-current

 

Total

 

Current

 

Non-current

 

Total

   
 
 
 
 
 
A. Cash   1,211       1,211   3,745         3,745
B. Cash equivalent   122       122   240         240
C. Available for sale securities and held-to-maturity securities   903   28   931   552         552
D. Liquidity (A+B+C)   2,236   28   2,264   4,537         4,537
E. Financial Receivables   12   247   259   143     252   395
F. Short-term financial liabilities towards banks   3,894       3,894   3,178         3,178
G. Long-term financial liabilities towards banks   296   1,926   2,222   131     2,180   2,311
H. Bonds   391   4,948   5,339   685     4,412   5,097
I. Short-term financial liabilities towards related parties   222       222   92         92
L. Long-term financial liabilities towards related parties       18   18         16   16
M. Other short-term financial liabilities   496       496   130         130
N. Other long-term financial liabilities   46   761   807   74     801   875
O. Total borrowings (F+G+H+I+L+M+N)   5,345   7,653   12,998   4,290     7,409   11,699
P. Net borrowings (O-D-E)   3,097   7,378   10,475   (390 )   7,157   6,767
   
 
 
 

 
 

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Available for sale securities and held-to-maturity securities of euro 552 million (euro 931 million at December 31, 2005) are made for non-operating purposes. The item does not include available for sale securities and held-to-maturity securities made for operating purposes of euro 441 million (euro 486 million at December 31, 2005) and primarily concern securities for covering technical reserves of Padana Assicurazioni SpA for euro 417 million (euro 453 million at December 31, 2005).
Financial receivables of euro 395 million (euro 259 million at December 31, 2005) are made for non-operating purposes. The item does not include financial receivables made for operating purposes of euro 246 million (euro 480 million at December 31, 2005), of which euro 241 million (euro 475 million at December 31, 2005) given to consolidated subsidiaries, joint ventures and affiliates primarily for the completion of industrial plans. Non current financial receivables of euro 252 million (euro 247 million at December 31, 2005) concern for euro 246 million a fixed deposit held by Eni Lasmo Plc as a guarantee on a debt issue (euro 241 million at December 31, 2005).


20 Provisions for contingencies
Provisions for contingencies of euro 8,614 million (euro 7,679 million at December 31, 2005) consist of the following:

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
Provisions for site restoration and abandonment   2,648   1,345   (188 )   (81 )   3,724
Provisions for environmental risks   2,103   272   (430 )   (40 )   1,905
Provisions for contract penalties and disputes   534   174   (62 )   8     654
Loss adjustments and actuarial provisions for Eni’s insurance companies   707   8   (127 )   (23 )   565
Provisions for taxes   309   48   (98 )   (38 )   221
Provisions for losses related to investments   85   65   (9 )   43     184
Provisions for revision of selling prices   321   104   (253 )         172
Provisions for restructuring or decommissioning   195   35   (73 )         157
Provisions for OIL insurance   127       (19 )         108
Provisions for onerous contracts   80   55   (35 )         100
Provisions for promotions and gifts   52   44   (46 )         50
Other (*)   518   518   (177 )   (85 )   774
    7,679   2,668   (1,517 )   (216 )   8,614
   
 
 

 

 
     
(*)   Each individual amount included herein does not exceed euro 50 million.

Provisions for site restoration and abandonment of euro 3,724 million represent primarily the estimated costs for well-plugging, abandonment and site restoration (euro 3,664 million). The increase of euro 1,345 million includes amounts recorded on initial recognition and changes to the estimates of dismantling and restoration of sites recognized as a balancing entry to the asset to which they refer (euro 1,240 million) and financial expense due to the passage of time charged to the profit and loss account (euro 105 million). The discount rates used range between 4.0% and 5.9%. Other changes of euro 81 million include exchange rate differences on the translation of financial statements prepared in currencies other than the euro for euro 102 million.
Provisions for environmental risks of euro 1,905 million represent, primarily, the estimated costs of remediation in accordance with existing laws and regulations, of active production facilities for Syndial SpA (euro 1,295 million), the Refining & Marketing segment (euro 346 million), the Corporate and financial companies segment, relating to guarantees issued in relation to properties sold (euro 117 million) and the Gas & Power segment (euro 78 million). Provisions in 2006 of euro 272 million primarily related to Syndial SpA (euro 125 million) and the Refining & Marketing segment (euro 79 million) and include additions due to the passage of time for euro 8 million. Deductions of euro 430 million primarily concern Syndial SpA (euro 225 million) and the Refining & Marketing segment (euro 146 million) and include deductions not corresponding to cash expenditures for euro 16 million.
Provisions for contract penalties and disputes of euro 654 million primarily include charges expected on contract penalties and general disputes. These provisions are stated on the basis of Eni’s best estimate of the expected probable liability. Provisions in 2006 for euro 174 million primarily related to Syndial SpA (euro 80 million) and the Gas & Power segment (euro 63 million). Deductions of euro 62 million include deductions not corresponding to cash expenditures for euro 25 million.

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Loss adjustments and actuarial provisions for Eni’s insurance companies of euro 565 million represent the liabilities accrued for claims on insurance policies underwritten by Padana Assicurazioni SpA. Deductions of euro 127 million concern deductions not corresponding to cash expenditures as regards to the reported accidents.
Provisions for taxes of euro 221 million primarily include charges for unsettled tax claims related to uncertain applications of the tax regulation for foreign companies of the Exploration & Production segment (euro 176 million). The decrease of euro 98 million concerns deductions not corresponding to cash expenditures for euro 32 million. Other changes of euro 38 million include the exchange rate differences on the translation of financial statements prepared in currencies other than the euro for euro 25 million.
Provisions for losses on investments of euro 184 million represent losses incurred to date in excess of the carrying value of investments (see Note 11 - Investments).
Provisions for the revision of selling prices of euro 172 million primarily concern the provision for the estimated adverse impact of the application of Resolution No. 248/2004 of the Italian Authority for Electricity and Gas affecting the parameters for upgrading the raw material component in price formulas for end users (euro 139 million). Deductions of euro 253 million concern deductions not corresponding to cash expenditures for euro 141 million primarily related to the adoption of the new tariffs’ regime introduced by Resolution No.134/2006 of the Italian Authority for Electricity and Gas (euro 139 million).
Provisions for restructuring or decommissioning of production facilities of euro 157 million mainly represent the estimated costs related to divestments and facilities shutdown in the Refining & Marketing segment (euro 124 million). Deductions of euro 73 million concern deductions not corresponding to cash expenditures for euro 17 million.
Provisions for OIL insurance of euro 108 million include the provisions related to the increase in charges to be paid within the next 5 years, due by Eni for its participation in the mutual insurance of Oil Insurance Ltd, following the increased number of accidents that occurred in 2004 and 2005.
Provisions for onerous contracts of euro 100 million essentially concern Syndial SpA and relate to contracts for which the termination or execution costs exceed the benefits arising from that contract.
Provisions for promotions and gifts of euro 50 million concern the provisions of the Refining & Marketing segment in relation to promotions directed towards the attainment of an increase on sales volumes on the Agip branded network and intended for service station managers, for truckers and motorists that perform the fuel fill-up at the "Isole Fai da Te".
Deductions of the other provisions for euro 177 million include deductions not corresponding to cash expenditures for euro 85 million, of wich euro 20 million concern provisions for long term construction contracts.


21 Provisions for employee benefits
Provisions for employee benefits of euro 1,071 million (euro 1,031 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
TFR   577   608
Pensions plans   318   268
Supplementary medical reserve for Eni managers (FISDE)   99   100
Other benefits   37   95
    1,031   1,071
   
 

Provisions for indemnities upon termination of employment essentially concern the provisions accrued by Italian companies for employee termination indemnities ("TFR"), regulated by Article 2120 of the Italian Civil Code. The indemnity is paid out as capital and is determined by the total of the provisions set aside, calculated in consideration of the employee’s compensation during the service period, and revalued until retirement. Provisions to TFR, considered for the determination of liabilities and costs, are net of the amounts paid to pension funds.
Effective from January 1, 2007 the Budget Law for 2007 and related decrees introduce material changes to the TFR regulation; these changes include the possibility for employees to choose the allocation of their TFR entitlement between a pension fund or having it remain in the company (in which case the company will transfer the future TFR obligation to INPS, the Italian state social security entity). At present there are uncertainties in interpretation regarding the recent changes in regulations. Furthermore, there is additional uncertainty arising from the revised regulations in respect to actuarial calculations on already accrued TFR provisions since it is currently not possible to predict employees’ choices regarding their allocation of the TFR entitlement (employees’ choice shall be made before June 30, 2007). Given this level of uncertainty, there has been no change made, which may result from the new regulations, to the amount of the TFR obligation recorded as at December 31, 2006.
Pension funds concern defined benefit plans of foreign companies located, primarily, in the United Kingdom, Nigeria and Germany. Benefits consist of a return on capital determined on the basis of the length of service and the compensation paid in the last year of service or an average annual compensation paid in a determined period preceding the retirement.

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The supplementary medical reserve for Eni managers (FISDE) is calculated on the basis of the contributions paid by the company for retired managers.
Other benefits primarily concern Jubilee awards and the deferred monetary incentive plan. Jubilee awards are benefits due following the attainment of a minimum period of service and, for the Italian companies, consist of an in-kind remuneration. Deferred monetary incentive plan reflects the estimate of the variable compensation dependent on the Company’s performance that will be paid in 2009 to Eni managers who reach individual defined objectives.
The value of employee benefits, estimated by applying actuarial techniques, consists of the following:

  Foreign pension plans  
 
 
(million euro)  

TFR

 

Gross liability

 

Plan asset

 

FISDE

 

Other benefits

 

Total

   
 
 
 
 
 
2005                                    
Current value of benefit liabilities and plan assets at beginning of year   577     576     (257 )   106     32     1,034  
Current cost   59     18           2     3     82  
Interest cost   25     30           5     1     61  
Expected return on plan assets               (16 )               (16 )
Employees contributions         1     (46 )               (45 )
Actuarial gains/losses   47     66     (24 )   (11 )   5     83  
Benefits paid   (49 )   (19 )   11     (6 )   (4 )   (67 )
Amendments         3                       3  
Curtailments or settlements   (6 )   (5 )                     (11 )
Exchange rate differences and other changes         87     (27 )               60  
Current value of benefit liabilities and plan assets at end of year   653     757     (359 )   96     37     1,184  
2006                                    
Current value of benefit liabilities and plan assets at beginning of year   653     757     (359 )   96     37     1,184  
Current cost   99     18           2     48     167  
Interest cost   22     28           3     6     59  
Expected return on plan assets               (24 )               (24 )
Employees contributions         (3 )   (88 )               (91 )
Actuarial gains/losses   (67 )   (2 )   (3 )   (5 )   6     (71 )
Benefits paid   (94 )   (16 )   12     (5 )   (2 )   (105 )
Amendments         2                       2  
Curtailments and settlements         (7 )   6                 (1 )
Exchange rate differences and other changes   1     (6 )   16                 11  
Current value of benefit liabilities and plan assets at end of year   614     771     (440 )   91     95     1,131  
   

 

 

 

 

 

Gross liability for employee benefits of foreign pension plans of euro 771 million (euro 757 million at December 31, 2005) includes liabilities of joint ventures operating in exploration and production activities for euro 130 million and euro 112 million at December 31, 2005 and 2006, respectively; a receivable was recorded against such liability.
Funds for other benefits of euro 95 million (euro 37 million at December 31, 2005) concern primarily Jubilee awards for euro 44 million (euro 29 million at December 31, 2005) and the deferred monetary incentive plan for euro 37 million.

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Changes in plan assets and benefit obligations related to provisions for employee benefits consist of the following:

    TFR   Foreign pension plans   FISDE   Other benefits
   
 
 
 
(million euro)   Dec. 31, 2005   Dec. 31, 2006   Dec. 31, 2005   Dec. 31, 2006   Dec. 31, 2005   Dec. 31, 2006   Dec. 31, 2005   Dec. 31, 2006
   
 
 
 
 
 
 
 
Current value of benefit obligations with plan assets at end of year               757     771                  
Current value of plan assets               (359 )   (440 )                
Net current value of benefit obligations with plan assets               398     331                  
Current value of benefit obligations without plan assets at end of year   653     614                 96   91   37   95
Actuarial gains/losses not recognized   (76 )   (6 )   (71 )   (63 )   3   9        
Past service cost not recognized               (9 )                      
Net liabilities recognized in provisions for employee benefits   577     608     318     268     99   100   37   95
   

 

 

 

 
 
 
 

Costs for employee benefits recognized in the income statement consist of the following:

(million euro)  

TFR

 

Foreign pension plans

 

FISDE

 

Other benefits

 

Total

   
 
 
 
 
2005                        
Current cost   59   18     2   3   82  
Interest cost   25   30     5   1   61  
Expected return on plan assets       (16 )           (16 )
Amortization of actuarial gains/losses                 6   6  
Effect of curtailments and settlements   (6 ) (5 )           (11 )
Other costs       3         1   4  
    78   30     7   11   126  
2006                        
Current cost   99   18     2   48   167  
Interest cost   22   28     3   6   59  
Expected return on plan assets       (24 )           (24 )
Amortization of actuarial gains/losses   2   21         5   28  
Effect of curtailments and settlements       (1 )           (1 )
Other costs   1                 1  
    124   42     5   59   230  
   
 

 
 
 

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The main actuarial assumptions used in the evalution of benefit obligations at year end in the estimate of costs for employee benefits expected for 2007 consist of the following:

(%)  

TFR

 

Foreign pension plans

 

FISDE

 

Other benefits

   
 
 
 
2005                
Discount rate   4.0   4.5-7.3   4.3   4.5-4.7
Expected return rate on plan assets       7.2        
Rate of compensation increase   2.7-4.5   3.0-5.8       3.5
Rate of price inflation   2.0   2.0-4.9   2.0   2.3-2.4
2006                
Discount rate   4.3   3.0-13.0   4.5   4.0-4.3
Expected return rate on plan assets       3.5-13.0        
Rate of compensation increase   2.7-4.0   2.0-12.0       2.7-4.5
Rate of price inflation   2.0   1.0-10.0   2.0   2.0-2.5
   
 
 
 

With regards to Italian plans, demographic tables prepared by Ragioneria Generale dello Stato (RG48) were used. The expected return rate of plan assets has been determined with reference to the ratings expressed in regulated markets.

Foreign plan assets consist of the following:

(%)  

Plan assets

 

Expected return

Dec. 31, 2006  
 
Securities   18.6   5.4-7.6
Bonds   60.3   2.6-9.4
Real estate   0.9   5-13
Other   20.2   2-13
Total   100.0    
   
 

The effective return of plan assets amounts to euro 27 million (euro 40 million at December 31, 2005).
With reference to medical plans, the effects deriving from a 1% change in the actuarial assumptions of the costs concerning medical consist of the following:

(million euro)  

1% Increase

 

1% Decrease

   
 
Impact on the current costs and interest costs   6   4
Impact on net benefit obligation   103   83
   
 

The amount of the contributions expected to be paid to the defined contribution plans for 2007 amounts to euro 68 million.
The analysis of the changes in net actuarial liabilities for the previous fiscal year deriving from the non-correspondence of the actuarial assumptions adopted in the previous fiscal year with the effective values recorded at the closing of the current fiscal year consists of the following:

(million euro)  

TFR

 

Foreign pension plans

 

FISDE

 

Other benefits

   
 
 
 
2005                    
Impact on net benefit obligation   47     59   (11 )    
Impact on plan assets         24          
2006                    
Impact on net benefit obligation   (19 )   13   (4 )   4
Impact on plan assets         3          
   

 
 

 

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22 Deferred tax liabilities
Deferred tax liabilities of euro 5,852 million (euro 4,890 million at December 31, 2005) are net of deferred tax assets for which Eni possesses the legal right of offset.

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Exchange rate differences

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
 
   

4,890

   

2,231

   

(676

)  

(379

)  

(214

)  

5,852

 
   
 
 
 
 
 

Other changes of euro 214 million include the set-off, for each company, of deferred tax assets and deferred tax liabilities for euro 318 million.
Deferred tax liabilities consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Deferred income taxes  

8,237

   

9,880

 
Deferred income taxes available for offset  

(3,347

)  

(4,028

)
   

4,890

   

5,852

 
Deferred income taxes not available for offset  

(1,861

)  

(1,725

)
Net deferred tax liabilities  

3,029

   

4,127

 
   
 

The most significant temporary differences giving rise to net deferred tax liabilities are the following:

(million euro)  

Value at Dec. 31, 2005

 

Additions

 

Deductions

 

Exchange rate differences

 

Other changes

 

Value at Dec. 31, 2006

   
 
 
 
 
 
Deferred tax liabilities:                                    
- accelerated tax depreciation   5,855     1,412     (414 )   (330 )   328     6,851  
- application of the weighted average cost method in evaluation of inventories   649     28     (108 )         80     649  
- site restoration and abandonment (tangible and intagible assets)   349     130     (36 )   (18 )   258     683  
- capitalized interest expense   245     2     (20 )         5     232  
- other   1,139     659     (98 )   (40 )   (195 )   1,465  
    8,237     2,231     (676 )   (388 )   476     9,880  
Deferred tax assets:                                    
- assets revaluation as per Law No. 342/2000 and No. 448/2001   (1,096 )         78           1     (1,017 )
- site restoration and abandonment (provisions for contingencies)   (1,038 )   (190 )   38     41     (347 )   (1,496 )
- depreciation and amortization   (868 )   (125 )   201     85     (37 )   (744 )
- accruals for impairment losses and provisions for contingencies   (839 )   (329 )   244     1     (77 )   (1,000 )
- tax loss carry forwards   (160 )   (10 )   96     10     (19 )   (83 )
- other   (1,207 )   (645 )   379     35     25     (1,413 )
    (5,208 )   (1,299 )   1,036     172     (454 )   (5,753 )
Net deferred tax liabilities   3,029     932     360     (216 )   22     4,127  
   

 

 

 

 

 

Deferred tax assets are recognized to the extent that expected future fiscal profits are considered sufficient for the utilization of these assets.
Under Italian fiscal laws, tax losses can be carried forward in the five subsequent periods, excepting losses suffered in the first three periods of life of the company that they can be carried forward without limit. Tax losses of foreign companies can be carried forward on average for more than five periods and for a considerable part they can be carried forward without limit. Tax recovery corresponds to a tax rate of 33% for Italian companies and to an average tax rate of 29.8% for foreign companies.

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Tax losses amount to euro 1,579 million and may be used within the following periods:

(million euro)  

Italian
companies

 

Foreign
companies

   
 
2007   4   17
2008   14   19
2009   13   13
2010       15
2011       37
after 2011       53
without limit   13   1,381
    44   1,535
   
 

Tax losses for which utilization is expected amount to euro 278 million and essentially concern foreign companies (euro 252 million); the related deferred tax assets amount to euro 83 million and concern for euro 75 million foreign companies. No deferred tax liabilities have been recognized in relation to the reserves of consolidated subsidiaries because such reserves are not expected to be distributed (euro 160 million).



23 Other non-current liabilities
Other non-current liabilities of euro 418 million (euro 897 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Payables related to capital expenditures   597     26  
Other payables   170     207  
Other liabilities   130     185  
    897     418  
   

 



24 Shareholders’ equity

Minority interest
Minority interest in net profit and shareholders’ equity relate to the following consolidated subsidiaries:

(million euro)  

Net profit

 

Shareholders’ equity

   
 
   

2005

 

2006

 

Dec. 31, 2005

 

Dec. 31, 2006

   
 
 
 
Snam Rete Gas SpA   321     287     1,158     1,004  
Saipem SpA   115     303     915     879  
Tigáz Tiszántúli Gázszolgáltató Részvénytársaság   6           82     79  
Others   17     16     194     208  
    459     606     2,349     2,170  
   

 

 

 

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Eni shareholders’ equity

(million euro)  

Value at
Dec. 31, 2005

 

Value at
Dec. 31, 2006

   
 
Share capital   4,005     4,005  
Legal reserve   959     959  
Reserve for treasury shares   5,345     7,262  
Treasury shares   (4,216 )   (5,374 )
Cumulative translation adjustment reserve   941     (398 )
Other reserves   5,351     400  
Retained earnings   17,381     25,168  
Net profit for the period   8,788     9,217  
Interim dividend   (1,686 )   (2,210 )
    36,868     39,029  
   

 

Share capital
At December 31, 2006 Eni SpA had 4,005,358,876 shares (nominal value euro 1 each) fully paid (the same amount as of December 31, 2005).
On May 25, 2006 Eni’s Shareholders Meeting decided a dividend distribution of euro 0.65 per share, with the exclusion of treasury shares held at the ex-dividend date, in full settlement of the 2005 dividend of euro 0.45 per share. The balance was made available for payment on June 22, 2006 and the ex-dividend date was June 19, 2006.

Legal reserve
The legal reserve of Eni SpA represents earnings restricted from the payment of dividends pursuant to Article 2430 of the Italian Civil Code.

Cumulative translation exchange differences reserve
The cumulative translation adjustment reserve represents exchange differences due to the translation of financial statements prepared in currencies other than the euro.

Reserve for treasury shares
The reserve for treasury shares represents the reserve destined to purchase shares in accordance with the decisions of Eni’s Shareholders’ Meetings. The amount of euro 7,262 million (euro 5,345 million at December 31, 2005) includes treasury shares purchased. The increase of euro 1,917 million primarily concerns the reclassification of euro 2,000 million following Eni’s Shareholders Meeting decision of May 25, 2006 and, as a decrease, the sale and grant of treasury shares to Group managers following stock option and stock grant plans for euro 85 million.

Treasury shares purchased
Treasury shares purchased amount to euro 5,374 million (euro 4,216 million at December 31, 2005) and consist of 324,959,866 ordinary shares at a nominal value of euro 1 owned by Eni SpA (278,013,975 ordinary shares at a nominal value of euro 1 euro at December 31, 2005). Treasury shares of euro 839 million (euro 237 million at December 31, 2005), are represented by 40,114,000 shares (17,428,300 shares at December 31, 2005) and are destined to the 2002-2005 and 2006-2008 stock option plans (38,240,400 shares) and the 2003-2005 stock grant plan (1,873,600 shares).

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The increase of 22,685,700 shares consists of the following:

   

Stock option

 

Stock grant

 

Total

   
 
 
Number of shares at December 31, 2005   14,004,500     3,423,800     17,428,300  
- rights granted for 2006-2008 stock option plan   30,000,000           30,000,000  
- rights not granted for 2003-2005 stock grant plans and 2002-2005 stock option plan   (624,900 )   (296,600 )   (921,500 )
- rights exercised   (4,943,200 )   (1,236,400 )   (6,179,600 )
- rights cancelled   (196,000 )   (17,200 )   (213,200 )
Number of shares at December 31, 2006   38,240,400     1,873,600     40,114,000  
   

 

 

At December 31, 2006, options and grants outstanding were 15,290,400 shares and 1,873,600 shares, respectively. Options refer to the 2002 stock plan for 238,000 shares with an exercise price of euro 15.216 per share, to the 2003 stock plan for 779,900 shares with an exercise price of euro 13.743 per share, to the 2004 stock plan for 3,108,500 shares with an exercise price of euro 16.576 euro per share, to the 2005 stock plan for 4,184,000 shares with an exercise price of euro 22.512 per share and to the 2006 stock plan for 6,980,000 shares with an weighted average exercise price of euro 23.119 per share.

Information about commitments related to stock grant and stock option plans is included in Note 27 - Operating expenses.

Other reserves
Other reserves of euro 400 million (euro 5,351 million at December 31, 2005) refer to a reserve constituted following the sale by Eni SpA of Snamprogetti SpA to Saipem Projects SpA for euro 247 million, to Eni SpA’s equity reserve for euro 146 million and for euro 7 million to the reserve for the valuation at fair value of securities available for sale and cash flow hedge derivatives. The decrease in other reserves essentially refers to the reclassification of euro 4,951 million from Eni's distributable reserve to retained earnings (euro 5,224 million).

The valuation at fair value of securities available for sale and cash flow hedge derivatives consists of the following:

    Security available for sale   Cash flow hedge derivatives   Total
   
 
 
(million euro)   Gross Reserve   Deferred Tax liabilities   Net Reserve   Gross Reserve   Deferred Tax liabilities   Net Reserve   Gross Reserve   Deferred Tax liabilities   Net Reserve
   
 
 
 
 
 
 
 
 
Reserve as of January 1, 2005   19     (6 )   13                       19     (6 )   13  
Changes of the year   8     (2 )   6     27     (11 )   16     35     (13 )   22  
Reserve as of December 1, 2005   27     (8 )   19     27     (11 )   16     54     (19 )   35  
Changes of the year   2           2     1           1     3           3  
Amount recognized in the                                                      
profit and loss account   (21 )   6     (15 )   (27 )   11     (16 )   (48 )   17     (31 )
Reserve as of December 31, 2006   8     (2 )   6     1           1     9     (2 )   7  
   

 

 

 

 

 

 

 

 

Interim Dividend
Interim dividend of euro 2,210 million concerns the interim dividend for the year 2006 of euro 0.60 per share, as decided by the Board of Directors in accordance with Article 2433-bis, paragraph 5 of the Italian Civil Code; the dividend was made available for payment on October 26, 2006.

Distributable reserves
At December 31, 2006 Eni shareholders’ equity included distributable reserves for approximately euro 32,000 million, a portion of which is subjected to taxation upon distribution. Deferred tax liabilities have been recorded in relation to the reserves expected to be distributed (euro 40 million).

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Reconciliation of statutory net profit and shareholders’ equity to consolidated net profit and shareholders’ equity

(million euro)  

Net profit

 

Shareholders’ equity

   
 
   

2005

 

2006

 

Dec. 31, 2005

 

Dec. 31, 2006

   
 
 
 
As recorded in Eni SpA’s Financial Statements (Italian GAAP)   6,042     5,821     26,872     26,935  
Difference between the equity value and result of consolidated                        
companies and the equity value and result of consolidated                        
companies as accounted for in Eni SpA Financial Statements   2,718     3,823     13,701     16,136  
Consolidation adjustments:                        
- difference between cost and underlying value of equity   (44 )   (52 )   1,902     1,138  
- elimination of tax adjustments and compliance with accounting policies   863     627     (1,528 )   (1,435 )
- elimination of unrealized intercompany profits   (40 )   (237 )   (2,677 )   (2,907 )
- deferred taxation   (313 )   (195 )   849     1,244  
- other adjustments   21     36     98     88  
    9,247     9,823     39,217     41,199  
Minority interest   (459 )   (606 )   (2,349 )   (2,170 )
As recorded in Consolidated Financial Statements (IFRS)   8,788     9,217     36,868     39,029  
   

 

 

 

 

 

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25 Guarantees, commitments and risks

Guarantees
Guarantees of euro 14,384 million (euro 12,862 million at December 31, 2005) consisted of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 

(million euro)

 

Unsecured guarantees

 

Other guarantees

 

Secured guarantees

 

Total

 

Unsecured guarantees

 

Other guarantees

 

Secured guarantees

 

Total

   
 
 
 
 
 
 
 
Consolidated companies       5,839       5,839       6,539       6,539
Unconsolidated subsidiaries   4   203       207   3   294       297
Affiliated companies and Joint Ventures   4,900   1,772   40   6,712   5,682   1,735       7,417
Others   64   40       104   79   52       131
    4,968   7,854   40   12,862   5,764   8,620       14,384
   
 
 
 
 
 
 
 

Guarantees given on behalf of consolidated companies of euro 6,539 million (euro 5,839 million at December 31, 2005) consist primarily of: (i) guarantees given to third parties relating to bid bonds and performance bonds for euro 3,467 million (euro 3,057 million at December 31, 2005), of which euro 2,726 million related to the Engineering & Construction segment (euro 2,397 million at December 31, 2005). The increase of euro 410 million primarily concerns the increase in the order backlog and the start of new works of the Engineering & Construction segment; (ii) VAT recoverable from tax authorities for euro 1,393 million (euro 1,386 million at December 31, 2005); (iii) insurance risk for euro 246 million reinsured by Eni (euro 298 million at December 31, 2005). At December 31, 2006 the underlying commitment covered by such guarantees was euro 6,160 million (euro 5,491 million at December 31, 2005).
Unsecured guarantees and other guarantees given on behalf of unconsolidated subsidiaries of euro 297 million (euro 207 million at December 31, 2005) consist of unsecured guarantees, letters of patronage and other guarantees given to commissioning entities relating to bid bonds and performance bonds for euro 288 million (euro 165 million at December 31, 2005). At December 31, 2006, the underlying commitment covered by such guarantees was euro 204 million (euro 145 million at December 31, 2005).
Unsecured guarantees, other guarantees and secured guarantees given on behalf of joint ventures and affiliated companies of euro 7,417 million (euro 6,712 million at December 31, 2005) primarily concern: (i) a guarantee of euro 5,654 million (euro 4,894 million at December 31, 2005) given by Eni SpA to Treno Alta Velocità - TAV - SpA for the proper and timely completion of a project relating to the Milan-Bologna train link by the Consorzio Eni per l’Alta Velocità - Cepav Uno; consortium members, excluding unconsolidated subsidiaries, gave Eni liability of surety letters and bank guarantees amounting to 10% of their respective portion of the work; (ii) unsecured guarantees, letters of patronage and other guarantees given to banks in relation to loans and lines of credit received for euro 1,214 million (euro 1,360 million at December 31, 2005), of which euro 756 million related to a contract released by Snam SpA (now merged into Eni SpA) on behalf of Blue Stream Pipeline Co BV (Eni 50%) to a consortium of international financing institutions (euro 844 million at December 31, 2005). At December 31, 2006, the underlying commitment covered by such guarantees was euro 2,470 million (euro 2,938 million at December 31, 2005).
Other guarantees given on behalf of third parties of euro 131 million (euro 104 million at December 31, 2005) consist primarily of guarantees given by Eni SpA to banks and other financing institutions in relation to loans and lines of credit for euro 87 million on behalf of minor investments or companies sold (euro 92 million at December 31, 2005). At December 31, 2006 the underlying commitment covered by such guarantees was euro 121 million (euro 75 million at December 31, 2005).

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Commitments and contingencies
Commitments and contingencies of euro 1,545 million (euro 1,655 million at December 31, 2005) consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Commitments        
Purchase of assets   219   9
Other   220   207
    439   216
Risks   1,216   1,329
    1,655   1,545
   
 

Obligations for purchase and sales of assets of euro 9 million decreased by euro 210 million. Such decrease was due to: (i) the extinguishment of the placement on the market of securities managed by Sofid Sim SpA. This company sold Italian Government bonds to investors and simultaneously entered into interest rate swaps with such investors wherein it received the rate of interest on such Italian Government bonds and paid a floating rate of interest linked to Euribor. Such investors could sell their securities back to Sofid Sim SpA at any time at par value plus related interest with the simultaneous cancellation of the related swaps (euro 116 million). The operation ended on January 1, 2006 following the expiry of the government bonds; (ii) to the acquisition from ESPI - Ente Siciliano per la Promozione Industriale (in liquidation) of 50% of the capital share of Siciliana Gas SpA and 1 share of Siciliana Gas Vendite SpA (euro 98 million).
Other commitments of euro 207 million (euro 220 million at December 31, 2005) are essentially related to a memorandum of intent signed with the Basilicata Region, whereby Eni has agreed to invest, also on account of Shell Italia E&P SpA, euro 181 million in the future in connection with Eni’s development plan of oil fields in Val d’Agri (euro 193 million at December 31, 2005).
Risks of euro 1,329 million (euro 1,216 million at December 31, 2005) primarily concern potential risks associated with the value of assets of third parties under the custody of Eni for euro 918 million (euro 794 million at December 31, 2005) and contractual assurances given to acquirors of certain investments and businesses of Eni for euro 393 million (euro 402 million at December 31, 2005).

Risk management

FOREWORD
The main risks identified and managed by Eni are the following:
(i) market risks deriving from the exposure to the fluctuations of interest rates, exchange rates between the euro and the US dollar and other currencies used by the company, as well as the volatility of commodity prices;
(ii) the credit risk deriving from the possible default of a counterparty;
(iii) the liquidity risk deriving from the risk that suitable sources of funding for the Group’s business activities may not be available;
(iv) country risk in oil & gas activities;
(v) the operation risk deriving from the occurrence of accidents, malfunctioning, failures with damage to persons and the environment affecting operating and financial results.

MARKET RISK
Market risk is the possibility that changes in currency exchange rates, interest rates or oil, natural gas and power prices will adversely affect the value of the group’s financial assets, liabilities or expected future cash flows. Their management follows a set of guidelines and procedures that concentrate the treasury function in two captive finance companies operating in the Italian and international financial markets. In particular, the finance company operating on the domestic market (Enifin) manages all the transactions concerning currencies and derivative financial contracts. Commodity risk is managed by each business unit while Enifin manages the negotiation of hedging derivatives. Starting on January 1, 2007, this task is being performed by Eni SpA following the incorporation of Enifin.
In order to minimize market risks related to changes in interest rates and exchange rates and to manage exposure to commodity prices fluctuations, Eni enters into various transactions using derivative financial instruments (derivatives). Derivatives are contracts whose value is derived from one or more underlying financial instrument, index or price that are defined in the contract. The group also trades derivatives in conjunction with these risk management activities. Eni does not enter into derivative transactions on a speculative basis.

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The control framework defined by Eni’ s guidelines prescribes that measurement and control of the market risk are to be performed on the basis of maximum acceptable levels of risk exposure defined in accordance with value-at-risk techniques. These techniques make a statistical assessment of the market risk, i.e., potential gain or loss in fair values.
Eni’s guidelines prescribe that Eni’s subsidiaries use such market risk exposure policies as to minimize market risk. Tolerable market risk exposure is set at the Group level within the central finance department which pools all risk positions of the Group. Calculation and measurement techniques followed by Eni are in accordance with established banking standards (such standards are established by the Basel Committee). However, the tolerable level of risk adopted by Eni is more conservative than the recommended one.
Eni’s guidelines prescribe that the exposure to risk from fluctuations in commodity prices is to be managed in a way as to maximize the value of the Group oil and gas production and sales volumes and to pursue set objectives of industrial margins. Risk exposure within trading activities is defined within maximum levels of value-at-risk attributed at each business unit, with the central function managing hedging request. Strategic risk exposure is monitored in terms of value-at-risk, albeit being not hedged in a systematic way.

EXCHANGE RATE RISK
Exchange rate risk derives from the fact that Eni’s operations are conducted in currencies other than the euro (in particular the US dollar) and with the time lag existing between the recording of costs and revenues denominated in currencies other than the functional currency and the actual time of the relevant monetary transaction (transaction exchange rate risk). Generally speaking, an appreciation of the US dollar versus the euro generally has a positive impact on Eni’s results of operations, and vice versa. Effective management of exchange rate risk is performed at the Group level, within the central finance department which matches contrarian positions of the Group operating subsidiaries and hedges net positions using derivatives (such as currency swaps, forwards and options). Such derivatives are recognized at fair value on the basis of market prices provided from specialized sources. Value-at-risk deriving from currency exposure is measured daily on the basis of a variance/covariance model, with a 99% confidence level and a 20-day holding period. The transaction currency risk on certain strategic holdings is deemed to be immaterial.

INTEREST RATE RISK
Variations in interest rates affect the market value of financial assets and liabilities of the company and the level of financial changes. Eni uses interest rate derivatives; such interest rate swaps and interest cross currency swaps are used to effectively manage the balance between fixed and floating rate debt. Such derivatives are recognized at fair value on the basis of market prices provided from specialized sources. Value-at-risk deriving from interest rate exposure is measured daily on the basis of a variance/covariance model, with a 99% confidence level and a 20-day holding period.

COMMODITY RISK
Eni’s results of operations are affected by changes in the prices of commodities. A decrease in oil, gas and product prices generally has a negative impact on Eni’s results of operations, and vice versa. In order to hedge commodity risk, Eni uses derivatives traded on the organized markets of ICE and NYMEX (futures and options) and derivatives traded over-the-counter (swaps, forwards and contracts for differences, with the underlying commodities being crude oil, refined products or electricity). Such derivatives are recognized at fair value on the basis of market prices provided from specialized sources or absent market prices, on the basis of estimates provided by brokers or suitable evaluation techniques. Value-at-risk deriving from commodity exposure is measured daily on the basis of a historical simulation technique, with a 95% confidence level and a one-day holding period.

CREDIT RISK
Credit risk is the potential exposure of the Group to loss in the event of non-performance by a counterparty. The credit risk arising from the Group’s normal commercial operations is controlled by individual operating units within Group-approved guidelines. The monitoring activity of credit risk exposure is performed at the Group level according to set guidelines and measurement techniques. In particular credit risk exposure to large clients and multi-business clients is monitored at the Group level on the basis of score cards quantifying risk levels. Eni’s guidelines define the characteristics of persons eligible to be counterparty of Eni in derivative contracts and cash management transactions. Eni constantly updates a list of eligible persons that includes highly credit-rated institutions. Eni has not experienced material non-performance by any counterparty. As of December 31, 2005 and December 31, 2006, Eni has no significant concentrations at credit risk.

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LIQUIDITY RISK
Liquidity risk is the risk that suitable sources of funding for the Group’s business activities may not be available. The group has long-term debt ratings of AA and Aa2, assigned respectively by Standard & Poor’s and Moody’s. The group has access to a wide range of funding at competitive rates through capital markets and banks and coordinates relationships with banks, borrowing requirements, foreign exchange requirements and cash management centrally.
At present, the Group believes it has access to sufficient funding and has also both committed and uncommitted borrowing facilities to meet currently foreseeable borrowing requirements.
Effective management of the liquidity risk has the objective of ensuring the availability of adequate funding to meet short term requirements and due obligations as well as the objective of ensuring a sufficient level of flexibility in order to fund the development plans of the Group’s businesses. This implies the adoption of a strategy to pursue an adequate structure of borrowing facilities (particularly the availability of committed borrowings facilities) and the maintenance of cash reserves.

COUNTRY RISK
Substantial portions of Eni’s hydrocarbons reserves are located in countries outside the EU and North America, certain of which may be politically or economically less stable than EU or North American countries. At December 31, 2006, approximately 70% of Eni’s proved hydrocarbons reserves were located in such countries. Similarly, a substantial portion of Eni’s natural gas supplies comes from countries outside the EU and North America. In 2006, approximately 60% of Eni’s domestic supply of natural gas came from such countries. Negative developments in the economic and political framework of these countries can temporarily or permanently compromise Eni’s ability to operate economically and to gain access to oil and natural gas reserves.
Eni constantly monitors the political, social and economic risk of the approximately 60 countries where it has invested or intends to invest with special attention to the evaluation of upstream investments. Country risks are mitigated by means of appropriate guidelines for risk management that Eni defined in its procedure for project risk assessment and management.

OPERATION RISK
The broad scope of Eni’s activities involves a wide range of operational risks such as those of explosion, fire or leakage of toxic products, and production of non biodegradable waste. All these events could possibly damage or even destroy plants, facilities, equipment and other property, cause injury or even death to persons or cause environmental damage.
Eni adopted the most stringent guidelines for the evaluation and management of health, safety and environmental (HSE) risks, with the objective of protecting Eni’s employees, contractors and clients, the populations involved in its activity, the environment and being in compliance with local and international rules and regulations. Eni’s guidelines prescribe the adoption of international best practices in setting internal principles, standards and solutions. An ongoing process for identifying, evaluating and managing HSE risks is at the heart of HSE operations in each phase of the business activity and is performed through the adoption of procedures tailored to the peculiarities of each business and industrial site.
HSE risks are effectively managed through an integrated management system designed along the principles set in Eni’s Model of HSE operations. This is a general procedure to be applied in all its operating sites, based on an annual cycle of planning, implementation, control, review of results and definition of new objectives. The model is directed towards the prevention of risks and a systematic monitoring and control of HSE performance in a continuous improvement cycle that is also subject to audits by internal and independent experts. Any environmental emergency is managed by business units locally with their own organization under preset reaction plans to foreseeable events aimed at limiting damage and at activating adequate responses.
Eni has two emergency rooms (in Milan and Rome) furnished with real time monitoring systems for the collection of data on georeferenced maps for all Eni sites and logistics worldwide. Meteorological equipment is in place to assess dimension, temporal development and other consequences of certain catastrophic events and to enable a real-time planning of first-aid interventions to help mitigate consequences. In addition to its own emergency teams, Eni entered international agreements in order to maximize its ability to react in all its operating sites.


Legal Proceedings

Eni is a party to a number of civil actions and administrative proceedings arising in the ordinary course of business. Based on information available to date, and taking the existing risk provisions into account, Eni believes that the foregoing will not have an adverse effect on Eni’s Consolidated Financial Statements.
The following is a description of the most significant proceedings currently pending; unless otherwise indicated below, no provisions have been made for these legal proceedings as Eni believes that negative outcomes are not probable or because the amount of the provision can not be estimated reliably.

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1. Environment

1.1 Criminal Proceedings

ENI SPA

(i)   Subsidence. In relation to the investigations concerning a subsidence phenomenon allegedly caused by hydrocarbon exploration and extraction activities, following the decision of the Court of Rovigo, the Nucleo Operativo Ecologico dei Carabinieri of Venice placed under preliminary seizure the Naomi/Pandora field and producing platform in 2002 and the Dosso degli Angeli field in 2004. Eni believes it has always acted in full compliance with existing laws under the required authorizations. Taking into account the observations of the consultants of the Court of Rovigo on which the public prosecutor based his case, Eni constituted an independent and interdisciplinary scientific commission, composed of prominent and highly qualified international experts of subsidence caused by hydrocarbon exploration and extraction activities, with the aim of verifying the size and effects and any appropriate actions to reduce or to neutralize any subsidence phenomenon in the Ravenna and North Adriatic area both on land and in the sea. This commission produced a study which denies the possibility for any risk for human health and for damage to the environment. It also states that no example is known anywhere in the world of accidents that caused harm to the public safety caused by subsidence induced by hydrocarbon production. The study also shows that Eni employs the most advanced techniques for the monitoring, measuring and control of the soil. This proceeding is in the first level hearing stage. The Veneto Region, the Ente Parco della Provincia del Po, the Province of Ferrara, the Province of Venice, the City of Venice, the City of Comacchio, the Province of Rovigo and two private entities have been acting as plaintiffs. Eni was accepted as a defendant in order to claim its own civil responsibilities. Parties are awaiting a decision from the Italian Supreme Court as to whether this proceeding has to take place before the Court of Rovigo or the Court of Adria.
(ii)   Alleged damage. In 2002, the public prosecutor of Gela started a criminal investigation in order to ascertain alleged damage caused by emissions of the Gela plant, owned by Polimeri Europa SpA, Syndial SpA (former EniChem SpA) and Raffineria di Gela SpA.
(iii)   Negligent fire in the refinery of Gela. In June 2002, in connection with a fire at the refinery of Gela, a criminal investigation began concerning negligent fire, environmental crimes and crimes against natural beauty.
(iv)   Investigation of the quality of ground water in the area of the refinery of Gela. In 2002, the public prosecutor of Gela started a criminal investigation concerning the refinery of Gela to ascertain the quality of ground water in the area of the refinery. Eni is charged of having breached environmental rules concerning the pollution of water and soil and of illegal disposal of liquid and solid waste materials.
(v)   Intentional poisoning (Priolo). In March 2002, the public prosecutor of Siracusa started an investigation concerning the activity of the refinery of Priolo in order to ascertain whether infiltrations of refinery products into the deep water-bearing stratum used for human consumption purposes in the Priolo area had occurred. The Court entrusted a company specialized in such field with the task of verifying the cause, origin and extension of the alleged infiltration. For protective purposes, remedial actions have been taken in order to: (i) create safety measures and clean-up of the polluted area; (ii) reallocate wells for drinking water in an area farther from and higher than the industrial site; and (iii) install a purification system for drinkable water. These actions are moving towards completion.
(vi)   Negligent fire (Priolo). The public prosecutor of Siracusa started an investigation against certain Eni managers who were previously in charge of conducting operations at the Priolo refinery (Eni divested this asset in 2002) in order to ascertain whether they acted with negligence in connection with a fire that occurred at the Priolo plants on April 30 and May 1-2, 2006. Preliminary investigations have almost been completed.

ENIPOWER SPA

(i)   Unauthorized waste management activities. In 2004 the public prosecutor of Rovigo started an investigation for alleged crimes related to unauthorized waste management activities in Loreo relating to the samples of soil used during the construction of the new EniPower power station in Mantova. The prosecutor requested the CEO of EniPower and the managing director of the Mantova plant at the time of the alleged crime to stand trial.
(ii)   Air emissions. The Prosecutor of Mantova started an investigation against two managers of the Mantova plant in connection with air emissions by the new power plant.

 

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POLIMERI EUROPA SPA
Violation of environmental regulations on waste management. Before the Court of Gela a criminal action took place relating to the alleged violation of environmental regulations on waste management concerning the ACN plant and the disposal of FOK residue deriving from the steam cracking process. Defendants were found guilty and a damage payment in first instance to an environmental association acting as plaintiff was required to be made. The amount of said damage payment is immaterial. The sentence was passed to the Civil Court for the quantification of any further damage and claim. Eni appealed the Court’s sentence.

RAFFINERIA DI GELA SPA
Soil and sea pollution. In 1999, the public prosecutor of Gela started an investigation in order to ascertain alleged soil and sea pollution caused by the discharge of pollutants by Eni’s Gela refinery. Three environmental organizations are acting as plaintiffs and have requested damage payment for euro 551 million. With a decision of February 20, 2007, the Court of Gela dismissed these allegations.

SYNDIAL SPA (FORMER ENICHEM SPA)
Criminal action started by the public prosecutor of Brindisi. In 2000, the public prosecutor of Brindisi started a criminal action against 68 persons who are employees or former employees of companies that owned and managed plants for the manufacture of dichloroethane, vinyl chloride monomer and vinyl polychloride from the early 1960s to date, some of which were managed by EniChem from 1983 to 1993. At the end of the preliminary investigation, the public prosecutor asked for the dismissal of the case in respect of the employees and the managers of EniChem. Plaintiffs presented oppositions and the prosecutor confirmed his request for dismissal of the case, rejecting such oppositions.

1.2 Civil and administrative proceedings

(i)   Pollution caused by the activity of the Mantova plant. In 1992, the Ministry of Environment summoned EniChem SpA and Montecatini SpA before the Court of Brescia. The Ministry requested, primarily, environmental remediation for the alleged pollution caused by the activity of the Mantova plant from 1976 until 1990, and provisionally, in case there was no possibility to remediate, the payment of environmental damages. EniChem acquired the Mantova plant in June 1989, as part of the Enimont deal. Parties agreed upon that Edison SpA would hold Eni harmless or pay compensatory damage for any damage caused to third parties by plant operations before Montedison’s sale, even if damage would manifests itself later. Parties agreed on a settlement by which Edison quantified the damage to be paid that also covers Syndial. The proceeding continues for the settlement of alleged damage pertaining to the residual 1989-1990 period.
(ii)   Summon before the Court of Venice for environmental damages caused to the lagoon of Venice by the Porto Marghera plants. On December 13, 2002, EniChem SpA, jointly with Ambiente SpA (now merged into Syndial SpA) and European Vinyls Corporation Italia SpA, was summoned before the Court of Venice by the Province of Venice. The province requested compensation for environmental damages that were not quantified, caused to the lagoon of Venice by the Porto Marghera plants, which were already the subject of two previous criminal proceedings against employees and managers of the defendants. In a related action, European Vinyls Corporation Italia presented an action for recourse against EniChem and Ambiente. Parties are waiting for the decision on the instances of the preliminary investigation.
(iii)   Claim of environmental damages, caused by industrial activities in the area of Crotone, commenced by the President of the Regional Council of Calabria. On April 14, 2003, the President of the Regional Council of Calabria, as Delegated Commissioner for Environmental Emergency in the Calabria Region, started an action against EniChem SpA related to environmental damages for approximately euro 129 million and damages for euro 250 million (plus interest and compensation) in connection with loss of income and damage to property allegedly caused by Pertusola Sud SpA activities (merged into EniChem) in the area of Crotone. In addition, the Province of Crotone is acting as plaintiff, claiming environmental damages for euro 300 million. The judge has yet to decide on the legitimacy of the Delegated Commissioner for Environmental Emergency in the Calabria Region to act on behalf of the Calabria Region. On October 21, 2004, Syndial was convened before the Court of Milan by the Calabria Region which is seeking to obtain a condemnation of Syndial for a damage payment, should the office of the Delegated Commissioner for Environmental Emergency in the Calabria Region cease during this proceeding. The Calabria Region requested damage payment amounting to euro 800 million as already requested by the Delegated Commissioner for environmental emergency in the Calabria Region in the proceeding started in 2003. This new proceeding is in the preliminary investigation stage.
On February 28, 2006, the Council of Ministers, Ministry for the Environment and Delegated Commissioner for environmental emergency in the Calabria Region represented by the State Lawyer requested Syndial to appear before the Court of Milan in order to obtain the ascertainment, quantification and payment of damage (in the form of land, air and water pollution and therefore of

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    the general condition of the population) caused by the operations of Pertusola Sud SpA in the Municipality of Crotone and in surrounding municipalities. The local authorities requested the ascertainment of Syndial’s responsibility as concerns expenses borne and to be borne for the cleanup and reclamation of sites, currently quantified at euro 129 million. This proceeding concerns the same matter and damage claim as the proceedings started by the Delegated Commissioner for environmental emergency in the Calabria Region and the Calabria Region against Syndial in 2003 and 2004, respectively.
(iv)   Summon for the ascertainment of responsibility in the pollution of soil at Paderno Dugnano. In 2004, Sitindustrie SpA, which in 1996 purchased a plant in Paderno Dugnano from Enirisorse (now merged into Syndial SpA), summoned Syndial SpA before the Court of Milan, requesting to establish the Syndial SpA’s responsibility in the alleged pollution of soil around the plant and to require it to pay environmental damage necessary for remediation. The Tribunal of Milan rejected the plaintiff’s request with a sentence released on June 10, 2006. The deadline to appeal the Tribunal sentence is November 1, 2007.
(v)   Summon for the ascertainment of responsibility in the pollution of soil at Pieve Vergonte. In October 2004, Sitindustrie SpA commenced an analogous proceeding against Syndial concerning the plant for the manufacture of products in copper and copper alloy in Pieve Vergonte.
(vi)   Summon for environmental damage caused by DDT pollution in Lake Maggiore. A proceeding is pending before the Court of Turin by which the Minister of the Environment summoned Syndial SpA and requested environmental damage for euro 2,396 million in relation to alleged DDT pollution of Lake Maggiore caused by the Pieve Vergonte plant. On March 1, 2006, the State Lawyer in an attempt to settle the case proposed Syndial to pay 10% of this claim corresponding to euro 239 million. This settlement attempt failed.
The Italian Ministry enacted a ministerial decree providing for the: (i) upgrading of a hydraulic barrier to protect the site; (ii) presentation of a project for the environmental remediation of Lake Maggiore. Syndial opposed this decree before an Administrative Court.
(vii)   Action started by the Municipality of Carrara for the remediation and reestablishment of previous environmental conditions at the Avenza site and payment of the environmental damage. The Municipality of Carrara started an action before the Court of Genova requesting Syndial SpA to remediate and reestablish previous environmental conditions at the Avenza site and the payment of certain environmental damage which cannot be cleaned up plus further damage of various genre (i.e., damage to the natural beauty of this site). This request is related to an accident that occurred in 1984, as a consequence of which EniChem Agricoltura SpA (later merged into Syndial SpA), at the time owner of the site, carried out safety and remediation works. The Ministry of the Environment joined the action and requested environmental damage payment – from a minimum of euro 53.5 million to a maximum of euro 93.3 million – to be broken down among the various companies that ran the plant in the past. In fact, Syndial summoned Rumianca SpA, Sir Finanziaria SpA and Sogemo SpA, who ran the plant in previous years, in order to be guaranteed. A report made by an independent expert charged by the Judge was filed with the Court. The findings of this report quantify the residual environmental damage at euro 15 million. A final decision on this proceeding is pending.
(viii)   Ministry for the Environment - Augusta harbor. The Italian Ministry for the Environment with variuos administrative acts ordered companies running plants in the petrochemical site of Priolo to perform safety and environmental remediation works in the Augusta harbor. Companies involved include Eni subsidiaries Polimeri Europa and Syndial. Pollution has been detected in this area primarily due to a high mercury concentration which is allegedly attributed to the industrial activity of the Priolo petrochemical site. Polimeri Europa opposed said administrative acts, objecting in particular the way by which remediation works have been designed and information on concentration of pollutants have been gathered.

2. Other judicial or arbitration proceedings

SYNDIAL SPA (FORMER ENICHEM SPA)

(i)   Serfactoring: disposal of receivables. In 1991, Agrifactoring SpA commenced proceedings against Serfactoring SpA, a company 49% owned by Sofid SpA which is controlled by Eni SpA. The claim relates to an amount receivable of euro 182 million for fertilizer sales (plus interest and compensation for inflation), originally owed by Federconsorzi to EniChem Agricoltura SpA (later Agricoltura SpA - in liquidation), and Terni Industrie Chimiche SpA (merged into Agricoltura SpA - in liquidation), that has been merged into EniChem SpA (now Syndial SpA). Such receivables were transferred by Agricoltura and Terni Industrie Chimiche to Serfactoring, which appointed Agrifactoring as its agent to collect payments. Agrifactoring guaranteed to pay the amount of such receivables to Serfactoring, regardless of whether or not it received payment on the due date. Following payment by Agrifactoring to Serfactoring, Agrifactoring was placed in liquidation and the liquidator of Agrifactoring commenced proceedings in 1991 against Serfactoring to recover such payments (equal to euro 182 million) made to Serfactoring based on the claim that the foregoing guarantee became invalid when Federconsorzi was itself placed in

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    liquidation. Agricoltura and Terni Industrie Chimiche brought counterclaims against Agrifactoring (in liquidation) for damages amounting to euro 97 million relating to acts carried out by Agrifactoring SpA as agent. The amount of these counterclaims has subsequently been reduced to euro 46 million following partial payment of the original receivables by the liquidator of Federconsorzi and various setoffs. These proceedings, which have all been joined, were decided with a partial judgment, deposited on February 24, 2004; the request of Agrifactoring has been rejected and the company has been ordered to pay the sum requested by Serfactoring and damages in favor of Agricoltura, to be determined following the decision. Agrifactoring appealed this partial decision, requesting in particular the annulment of the first step judgment, the reimbursement of euro 180 million from Serfactoring along with the rejection of all its claims and the payment of all proceeding expenses. The hearing of the pending appeal was set for March 16, 2007 but was rescheduled to October 27, 2007 upon request of Agrifactoring. The judge of the Court of Rome, responsible for the determination of the amount of damages to be paid to Serfactoring and Agricoltura decided on May 18, 2005 to suspend this determination until the publication of the decision of the Court of Appeals. On argument, Serfactoring and Syndial requested that the Court of Cassation cancel the suspension and return the case to its original court.
(ii)   Breach of a preliminary agreement for the purchase of an industrial area in Ravenna. In 2002, EniChem SpA was summoned by ICR Intermedi Chimici di Ravenna Srl before the Court of Milan in relation to a breach of a preliminary agreement for the purchase of an industrial area in Ravenna. ICR requested payment of compensatory damage for approximately euro 46 million, of which euro 3 million are compensatory damage and euro 43 million are for loss of income. With a sentence of October 11, 2005, the Court rejected ICR’s request and ordered that ICR pay all proceeding expenses. ICR filed a claim against this decision, reducing its original claim to euro 8 million. A final decision is pending.

3. Antitrust, EU Proceedings, Actions of the Italian Authority for Electricity and Gas and of Other Regulatory Authorities

3.1 Antitrust

ENI SPA

(i)   Abuse of dominant position of Snam verified by the AGCM. In March 1999, the Italian Antitrust Authority ("AGCM") concluded its investigation started in 1997 and: (i) verified that Snam SpA (merged in Eni SpA in 2002) abused its dominant position in the market for the transportation and primary distribution of natural gas relating to the transportation and distribution tariffs applied to third parties and the access of third parties to infrastructure; (ii) fined Snam euro 2 million; and (iii) ordered a review of these practices relating to such abuses. Snam believes it has complied with existing legislation and appealed the decision with the Regional Administrative Court of Lazio requesting its suspension. On May 26, 1999, stating that these decisions are against Law No. 9/1991 and the European Directive 98/30/EC, this Court granted the suspension of the decision. The Authority did not appeal this decision. The decision on the merit of this dispute is still pending before the same Administrative Court.
(ii)   Inquiry of the AGCM on jet fuel. With a decision of December 9, 2004, the Italian Antitrust Authority commenced an inquiry on the distribution of jet fuel against six oil companies operating in Italy, including Eni and certain entities jointly controlled by said oil companies engaged in the storing and loading of jet fuel in the Rome Fiumicino, Milan Linate and Milan Malpensa airports. The inquiry intends to ascertain the existence of alleged restrictions to competition as said oil companies would agree to divide among themselves the supplies to airlines. On December 22, 2005, the Authority notified the preliminary results of the inquiry concerning: (i) information flows to said oil companies related to the functioning of the jointly-controlled entities engaging in the storage and uploading of jet fuel; (ii) barriers to the entrance of new competitors in the capital of such entities operating the activities of storing and loading; and (iii) the price of jet fuel which is deemed to be higher than on other European markets.
On June 20, 2006, the Authority notified the final decision of this proceeding to Eni and fined Eni by an amount of euro 117 million. The Authority fined other oil companies involved in this matter. Eni filed an opposition against this decision before an administrative court and suspended the payment of this fine. On January 29, 2007, the Regional Administrative Court of Lazio accepted only partially the opposition made by Eni and annulled part of the decision of the Authority. In particular, a measure providing for the involved oil companies to cease their joint participation in the capital of the entities operating the activities of storing and loading jet fuel was annulled. Eni accrued a provision with respect to this proceeding.
(iii)   Formal assessment started by the Commission of the European Communities for the evaluation of alleged participation to activities limiting competition in the field of paraffin. On April 28, 2005, the Commission of the European Communities started a formal assessment to evaluate the alleged participation of Eni and its subsidiaries to

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    activities limiting competition in the field of paraffin. The alleged violation of competition would have consisted in: (i) the determination of and increase in prices; (ii) the subdivision of customers; and (iii) exchange of trade secrets, such as production capacity and sales volumes. Subsequently, the Commission requested information on Eni’s activities in the field of paraffins and certain documentation acquired by the Commission during an inspection. Eni filed the requested information.
(iv)   Notification to Eni Petroleum Co Inc of a subpoena by the Department of Justice of the United States of America - Antitrust Division and request of information and documents relating to activities in the field of wax and of a deposition. On April 28, 2005, the Department of Justice of the United States of America - Antitrust Division, notified Eni Petroleum Co Inc of a subpoena requesting information and documents relating to activities in the field of wax to be filed before June 20, 2005 and a deposition on the same date. The Company informed the department that it does not produce nor import wax in the United States of America.
(v)   Inquiry started by the AGCM concerning an alleged abuse of dominant position in the use of the total continuous regasification capacity of GNL. On November 18, 2005, the Italian Antitrust Authority notified Eni and its subsidiary GNL Italia the opening of an inquiry, in accordance with Article 14 of Law No. 287/1990, concerning an alleged abuse of dominant position in the assignment and use of the total continuous regasification capacity of the Panigaglia terminal (owned by GNL Italia) during thermal years 2002-2003 and 2003-2004, as already reported by an inquiry of the Italian Authority for Electricity and Gas on the same matter as the inquiry of the Antitrust Authority. The Authority for Electricity and Gas closed its inquiry by signalling the fact to the Antitrust Authority. In a later communication Eni was informed that the inquiry has been extended also to thermal year 2004-2005 and to Snam Rete Gas which is the parent company of GNL Italia SpA. On September 25, 2006, the Antitrust Authority sent Eni the findings of its inquiry. Subsequently, Eni presented the Antitrust Authority certain commitments based on Article 14-ter of Law No. 287/1990. On November 23, 2006, the Antitrust Authority resolved to publish such commitments effective the following day. On March 6, 2007, the Antitrust Authority resolved to accept Eni’s commitments and to close the inquiry without recognizing any charge to Eni and imposing any fine whatsoever. Eni is committed to perform a gas release amounting to 4 billion cubic meters in a two-year period, starting on October 1, 2007.
(vi)   Ascertainment by the European Commission of the level of competition in the European natural gas market. As part of its activities to ascertain the level of competition in the European natural gas market, with decision No. C(2006)1920/1 of May 5, 2006, the European Commission informed Eni on May 16, 2006 that Eni and its subsidiaries were subject to an inquiry under Article 20, paragraph 4 of the European Regulation No. 1/2003 of the Council in order to verify the possible existence of any business conducts breaching European rules in terms of competition and intended to prevent access to the Italian natural gas wholesale market and to subdivide the market among few operators in the activity of supply and transport of natural gas.
Officials from the European Commission conducted inspections at headquarters of Eni and of certain Eni subsidiaries and collected documents. Similar actions have been performed by the Commission also against the main operators in natural gas in Germany, France, Austria and Belgium.
(vii)   TTPC. In April 2006, Eni filed a claim before the Regional Administrative Court of Lazio against the decision of the Italian Antitrust Authority of February 15, 2006 stating that Eni’s behaviour pertaining to implementations of plans for the upgrading of the TTPC pipeline for importing natural gas from Algeria represented an abuse of dominant position under Article 82 of the European Treaty and fined Eni. The initial fine amounted to euro 390 million and was reduced to euro 290 million in consideration of Eni’s commitment to perform actions favoring competition among which the upgrading of said gasline. Eni accrued a provision with respect to this proceeding. With a decision filed on November 29, 2006, the Regional Administrative Court of Lazio partially accepted Eni’s claim, annulling such part of the Authority’s decision where the fine was quantified. Eni is waiting for the filing of the motivations of the Court decision to ascertain the impact of said decision. Pending this development, the payment of the fine has been voluntarily suspended.
(viii)   Inquiry of the AGCM in relation to collusive mechanisms for the pricing of automotive fuels distributed on the retail market. With a decision of January 18, 2007, the Italian Antitrust Authority opened an inquiry to ascertain the existence of a possible agreement to limit competition in the field of pricing of automotive fuels distributed on the retail market in Italy in violation of Article 81 of the EC Treaty. This inquiry concerns eight oil companies, among which Eni. According to the Authority, said companies would have been putting in place collusive mechanisms intended to influence the pricing of automotive fuels distributed on the retail market by way of a continuing exchange of informative flows since 2004.With decision of January 18, 2007, the Italian Antitrust Authority opened an inquiry to ascertain the existence of a possible agreement limit competition in the field of pricing of automotive fuels distributed on the retail market in Italy in violation of Article 81 of the EC Treaty. This inquiry concerns eight oil companies, among which Eni. According to the Authority, said companies would have been putting in place collusive mechanisms intended to influence the pricing of automotive fuels distributed on the retail market by way of a continuing exchange of information flows since 2004.

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POLIMERI EUROPA SPA AND SYNDIAL SPA
Inquiries in relation to alleged anti-competitive agreements in the area of elastomers.
In December 2002, inquiries were commenced concerning alleged anti-competitive agreements in the area of elastomers. These inquiries were commenced concurrently by European and U.S. authorities. The first product under scrutiny was EP(D)M: the European Commission submitted to inspection the manufacturing companies of that product, among which Polimeri Europa SpA and Syndial and requested information from those two companies and to their parent company, Eni SpA. After the inquiries the Commission decided to open a procedure for violation of competition laws and notified Eni, Polimeri Europa and Syndial the relevant charges to that effect on March 8, 2005. At a hearing held on July 27, 2005 the two companies presented memoranda and confirmed their position. Eni and its subsidiaries are waiting for a decision on part of the European Commission.
EP(D)M manufacture is also under scrutiny in the United States, where the Department of Justice of San Francisco requested information and documents to Polimeri Europa Americas Inc, a U.S. subsidiary of Polimeri Europa and to its deputy chairman and sales manager. Class actions were filed claiming damages in relation to the alleged violation. On July 2005, Syndial signed a settlement agreement for the civil class action which entails the payment of approximately $3.2 million, approved by the federal court. The investigation was also extended to the following products: NBR, CR, BR, SSBR and SBR. The European Commission started an investigation regarding BR, SBR, SSBR. On January 26, 2005, the European Commission dropped the charges in relation to SSBR. Investigations regarding BR, SBR and EPDM led to the notification of relevant charges. A hearing took place before the European Commission. On July 26, 2006, the European Commission notified the dismissal of the EPDM matter to Eni. Regarding the other two products BR and SBR, on November 29, 2006, the Commission fined a number of European operators, among which Eni, an amount of euro 519 million based on the charge of having established a trust in the field of synthetic rubber production. Eni and its subsidiary Polimeri Europa were fined by an overall amount of euro 272.25 million. Eni and its subsidiary are preparing an appeal against this decision claiming in particular the existence of the infringing behavior and the amount of the fine, and the fact that Eni is accountable for the behavior of its subsidiaries.
With regard to NBR, an inquiry is underway in Europe and the U.S., where class actions have also been started. On the federal level, the class action was abandoned by the plaintiffs. The federal judge has yet to acknowledge this abandonment. With regard to CR, as part of an investigation carried out in the U.S., Syndial entered into a plea agreement with the Department of Justice pursuant to which Syndial would agree to pay a fine of $9 million, while the Department of Justice would agree that it will not bring further criminal charges against Syndial or against its affiliated companies. On June 27, 2005 the plea agreement was approved. As regards CR, the civil class action was closed with a settlement agreement approved by the federal judge on July 8, 2005 whereby the company will pay $5 million.
Eni recorded a provision for these matters.

3.2 Regulation

Inquiry of the Italian Authority for Electricity and Gas regarding the use of storage capacity conferred in years 2004-2005 and 2005-2006. With Decision No. 37 of February 23, 2006, the Italian Authority for Electricity and Gas commenced an inquiry on a few natural gas selling companies, among which Eni, in order to possibly impose a fine or an administrative sanction regarding the use of storage capacity conferred in years 2004-2005 and 2005-2006.
For the 2004-2005 thermal year and for the period from October 1, 2005 to December 31, 2005, the Authority for Electricity and Gas supposed that given the weather of the period, the use of modulation storage capacity was featured by a higher volume of off takes with respect to the volume which would have been necessary to satisfy the commercial requirements for which the storage company entitled Eni to a priority in the conferral of storage capacity. According to the Authority for Electricity and Gas, such situation was in contrast with applicable regulation.
Eni presented an articulated and documented memorandum to claim the thesis of the Authority for Electricity and Gas regarding the alleged non compliance of Eni's behavior with regulation in force, also taking account of the circumstances under which excess off takes occurred and the subsequent authorization of the Ministry for Economic Development to use the strategic storage for the thermal year 2004-2005. With Decision No. 281/2006 of December 6, 2006, the Authority for Electricity and Gas closed said inquiry and fined Eni by euro 90 million of which euro 45 million pertaining to the thermal year 2004-2005 and euro 45 million to the thermal year 2005-2006 as a consequence of Eni having violated regulation in force pertaining to the priorities in the conferral of storage capacity.
Eni plans to pay the amount of this fine pertaining to the thermal year 2004-2005 in accordance to a reduced form as provided by Law No. 689/1981and to appeal Decision No. 281/2006 of the Authority for Electricity and Gas before the Regional Administrative Court of Lombardia requesting the Tribunal: (i) for the first thermal year, to ascertain whether Eni is legitimate to pay in a reduced form or, in case Eni is not legitimate to do so, to annul the fine; (ii) for the second thermal year, to annul the fine. Eni accrued a provision for this proceeding.

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STOCCAGGI GAS ITALIA SPA
Tariffs
. With Decision No. 26 of February 27, 2002, the Italian Authority for Electricity and Gas determined tariff criteria for modulation, mineral and strategic storage services for the period from April 1, 2002 to March 31, 2006 and effective retroactively from June 21, 2000. On March 18, 2002 Stoccaggi Gas Italia SpA (Stogit) filed its proposal of tariff for modulation, mineral and strategic storage for the first regulated period. With Decision No. 49 of March 26, 2002, the Authority for Electricity and Gas repealed Stogit’s proposal and defined tariffs for the first regulated period. Stogit applied the tariff determined by the two decisions, but filed an appeal against both decisions with the Regional Administrative Court of Lombardia requesting their cancellation. With a decision dated September 29, 2003, that court rejected the appeal presented by Stogit. Stogit filed an appeal to the Council of State against the sentence which was rejected by the Council of State on January 6, 2006.

DISTRIBUIDORA DE GAS CUYANA SA
Formal investigation of the agency entrusted with the regulation of the natural gas market in Argentina ("Enargas").
The agency entrusted with the regulation of the natural gas market in Argentina ("Enargas") started a formal investigation on some operators, among these Distribuidora de Gas Cuyana SA, a company controlled by Eni. Enargas stated that the company improperly applied calculated conversion factors to volumes of natural gas invoiced to customers and requested the company to apply the conversion factors imposed by local regulations from the date of the default notification (March 31, 2004) without prejudice to any damage payment and fines that may be decided after closing the investigation. On April 27, 2004, Distribuidora de Gas Cuyana presented a defense memorandum to Enargas, without prejudice to any possible appeal. On April 28, 2006, the Company filed a formal request for examining the documents used as evidence of the alleged violation.

4. Tax Proceedings

ENI SPA
With a decree dated December 6, 2000, the Lombardia Region decided that natural gas used for electricity generation is subject to an additional regional excise tax in relation to which Snam SpA (merged into Eni SpA in 2002) should substitute for the tax authorities in its collection from customers. Given interpretive uncertainties, the same decree provides the terms within which distributing companies are expected to pay this excise tax without paying any penalty. Snam SpA and the other distributing companies of Eni believe that natural gas used for electricity generation is not subject to this additional excise tax. For this reason, an official interpretation was requested from the Ministry of Finance and Economy. With a decision of May 29, 2001, the Ministry confirmed that this additional excise tax cannot be applied. The Region decided not to revoke its decree and Snam took appropriate legal action. On the basis of action carried out by Snam, the Council of State decided on March 18, 2002 that the jurisdiction of the Administrative court did not apply to this case. In case the Region should request payment, Eni will challenge this request in the relevant Court. The Lombardia Region decided with regional Law No. 27/2001 that no additional tax is due from January 1, 2002 onwards, but still requested the payment of taxes due before that date. The action for the recognition of such taxes bears a five-year term. Consequently, the exercise of such action expires on July 16, 2007.
With a formal assessment presented by the Municipality of Pineto (Teramo), Eni SpA has been accused of not having paid a municipal tax on real estate for the period from 1993 to 1998 on four oil platforms located in the Adriatic Sea territorial waters in front of the coast of Pineto. Eni was requested to pay a total of approximately euro 17 million including interest and a fine for lacking payment and tax declaration. Eni filed a claim against this request stating that the sea where the platforms are located is not part of the municipal territory and the tax application as requested by the municipality lacked objective fundamentals. The claim has been accepted in the first two degrees of judgment at the Provincial and Regional Tax Commissions. But the Court of Cassation cancelled both judgments declaring that a municipality can consider requesting a tax on real estate also in the sea facing its territory and with a decision of February 21, 2005 sent the proceeding to another section of the Regional Tax Commission in order to judge on the other reasons opposed by Eni. On December 28, 2005, the Municipality of Pineto presented the same request for the same platforms for the years 1999 to 2004. The total amount requested from Eni is euro 24 million. Eni filed a claim against this request.

SNAM RETE GAS SPA
Environmental tax of the Sicilia Region upon the owners of primary pipelines.
With Regional Law No. 2 of March 26, 2002, the Sicilia Region introduced an environmental tax upon the owners of primary pipelines in Sicily (i.e., pipelines operating at a maximum pressure of over 24 bar). The tax was payable as of April 2002. In order

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to protect its interests, Snam Rete Gas filed a claim with the European Commission, aimed at opening a proceeding against the Italian Government and the Tax Commission of Palermo. The Authority for Electricity and Gas, although acknowledging that the tax burden is an operating cost for the transport activity, subjected inclusion of the environment tax in tariffs to the final ruling on its legitimacy by relevant authorities. With the ruling of December 20, 2002, the Court judged the tax at variance with European rules. In December 2002, Snam Rete Gas suspended payments based on the above Court ruling. Payments effected until November 2002 totaled euro 86.1 million. In January 2003, the Sicilia Region filed an appeal with the Council of State against the ruling of the Regional Administrative Court of Lombardia for the part that states the variance of the regional law with European rules. On December 16, 2003, the European Commission judged the tax instituted by the Republic of Italy, through the Sicilia Region, to be contrary to European rules and to the cooperation agreement between the European Economic Community and the Peoples’ Democratic Republic of Algeria; the European Commission also stated that such environmental tax is in contrast with the common customs tariff because it modifies the equality of customs expenses on commodities imported from third countries and could create a deviation in trade with such countries and a distortion in access and competition rules. The Commission with its opinion presented on July 7, 2004 formally requested Italy to cancel the tax. The Italian Government was ordered to conform within two months from receipt of the opinion. As it did not conform, on December 20, 2004 the European Commission passed the case to the Court of Justice requesting a ruling. With a decision dated January 5, 2004, and confirmed on March 4, 2005 by the Regional Tax Commission, the Provincial Tax Commission of Palermo declared the environmental tax of the Sicilia Region illegitimate because it is contrary to European rules and therefore accepted Snam Rete Gas’s claim for the repayment of the first installment of euro 10.8 million, already paid to the Sicilia Region in April 2002. On May 4, 2004, the Sicilia Region repaid the first installment. As for the seven remaining installments paid after April 2002 (euro 75.3 million), the Provincial Tax Commission of Palermo with decision of January 5, 2005 confirmed the illegitimacy of the tax condemning the Region to repay the cashed amounts and accrued interest to Snam Rete Gas. The Sicilia Region presented recourse against said decision before the Regional Tax Commission at Palermo on April 15, 2005. The relevant hearing was held on April 5, 2006. On January 17, 2007, decisions were filed pertaining to four out of seven recourses presented by the Sicilia Region; each of said recourses corresponds to an installment of the tax paid by Snam Rete Gas. Said decisions rejected the recourses presented by the Sicilia Region. Snam Rete Gas expects similar developments with regard to residual recourses.

AGIP KARACHAGANAK BV
Claims concerning unpaid taxes and relevant payment of interest and penalties.
In July 2004, relevant Kazakh authorities informed Agip Karachaganak BV and Agip Karachaganak Petroleum Operating BV, shareholder and operator of the Karachaganak contract, respectively, on the final outcome of the tax audits performed for fiscal years 2000 to 2003. Claims by the Kazakh authorities concern unpaid taxes for a total of $43 million, net to Eni, and the anticipated offsetting of VAT credits for $140 million, net to Eni, as well as the payment of interest and penalties for a total of $128 million. Both companies filed a counterclaim. With an agreement reached on November 18, 2004, the original amounts were reduced to $26 million net to Eni that includes taxes, surcharges and interest. Meetings continue regarding residual matters. Eni recorded a provision for this matter.

5. Settled Proceedings

RAFFINERIA DI GELA SPA
With a sentence released in July 2006, the Court of Gela ascertained that certain alleged crimes pertaining to the emissions of the refinery had become extinct due to the statute of limitations. In relation to such alleged crimes, the Court of Gela summoned the legal representatives of the company for events that have occurred since 1997. The Municipality of Gela, the Province of Caltanissetta and others acted as plaintiff in this proceeding, requesting the payment of compensatory damages for a total of euro 878 million.

SYNDIAL SPA
Personal cautionary measures against some employees of the Priolo plant issued by the Court of Siracusa concerning illicit management relating to waste activities.
On January 16, 2003, the Court of Siracusa issued personal cautionary measures against several employees of the Priolo plant owned by EniChem SpA and Polimeri Europa SpA, within judicial investigations pertaining to an illicit management relating to the production, disposal and treatment of liquid and solid waste materials resulting in an illicit income from the savings arising from the non compliance with rules regulating waste activities. Polimeri Europa and EniChem acted as plaintiffs. Findings of the preliminary investigations were notified to involved persons, confirming accusations. During the

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preliminary investigations, traces of mercury were found in the sea. The public prosecutor of Siracusa started an inquiry for ascertaining the conditions of sediments and marine fauna in the bay of Augusta. According to the prosecutor, mercury was spilled into the sea and poisoned the marine fauna and therefore resulted in fetal malformations and abortions due to the consumption of contaminated seafood fished in this area. The chlorine soda plant, built in the late 1950s was contributed in-kind to Syndial in 1989 when the Enimont joint venture was formed. It was therefore proved that Eni’s employees held no responsibility for the crimes of which they were charged. On March 15, 2006, the judge for preliminary investigations decided the dismissal of the case against Syndial employees, accepting the request made by the prosecutor.

SYNDIAL SPA (FORMER ENICHEM SPA)
In 1997, an action was commenced before the Court of Venice concerning the criminal charges brought by the Venice public prosecutor for alleged mismanagement of the Porto Marghera plant starting in the 1970s until 1995 and for the alleged pollution and health damage resulting there from. Defendants included certain employees of Eni which have managed the Porto Marghera plant since the beginning of the eighties. On November 2, 2001, the Court of Venice acquitted all defendants. The appeal against the decision was presented by the public prosecutor, the state attorney on behalf of the Ministry of Environment and the Council of Ministers, five public entities, 12 associations and other entities and 48 individual persons. On December 15, 2004 the Venice Court of Appeals confirmed the preceding judgment, changing only some marginal parts. As concerns some defendants, the Venice Court of Appeals decided not to proceed due to the statute of limitations for some crimes, while it confirmed the preceding judgment for the other matters. On May 19, 2006, the Court of Final Instance, before which plaintiffs appealed the decision of the Venice Court of Appeals, acquitted all defendants stating that pollution and mismanagement of the plant occurred before the 1980s and consequently Eni and its employees could not be deemed responsible. In January 2006, Eni settled this matter with the Council of Ministers and the Ministry for the Environment paying an amount of euro 40 million. Under terms of the settlement, the latter will abstain from recourse to the Court of Final Instance and will not act on any other environmental damage concerning the management of Porto Marghera until the date of the settlement. Eni already recorded a provision for this matter which was sufficient to cover the amount of the settlement.

ENI DACIÓN BV
In August 2005, the internal revenue service of Venezuela served four formal assessment on income taxes to Eni Dación BV for the years 2001 to 2004 that, by excluding the deductibility of certain costs: (i) annul the losses recorded for the periods amounting to a total of bolivar 910 billion (corresponding to $425 million); (ii) determine for the same periods a taxable income amounting to a total of bolivar 115 billion (corresponding to $54 million); and (iii) request a tax amounting to bolivar 52 billion (corresponding to $24 million) determined by applying a 50% tax rate rather than the 34% rate applied to other companies performing activities analogous to those of Eni Dación BV. In particular, it excluded the deductibility of: (i) interest charges due to other Eni Group companies that provided loans denominated in U.S. dollars; and (ii) exchange rate losses recorded in the financial statements and related to such loans resulting from the devaluation of the Venezuelan currency. The formal assessments served have a preliminary nature and do not request immediate payment nor do they specify the amount of a fine (from 10 to 250%) and of interest (average rate for the period approximately 23%). Eni Dación filed a claim for the cancellation of the assessment. In the 2005 accounts, Eni recorded a specific provision for this matter. In April 2006, the appeal was rejected and the final tax assessment was issued. The final tax assessment: (i) substantially confirmed the preliminary assessments, although reducing the originally assessed income tax liability to bolivar 39 billion ($18 million); and (ii) imposed fines and late payment interests of bolivar 109 billion ($51 million). Eni Dación BV presented a further administrative appeal before the expiration of the time limit for filing a judicial tax appeal, thereby obtaining a reduction of the overall amount from bolivar 148 billion ($69 million) to bolivar 52 billion ($24 million) including taxes in the amount of bolivar 12.5 billion ($6 million) and fines and late payment interest in the amount of bolivar 39.5 billion ($18 million). In order to avoid further charges deriving from the increase of the corresponding fines and late payment interest, Eni Dación BV paid the newly assessed amount in May 2006, thereby reaching a settlement. Consistently, Eni Dación BV filed an integrative income tax return for year 2005, considering the new tax bases for years 2001 to 2004, and paid accordingly bolivar 128 billion ($60 million) of income taxes and bolivar 4.4 billion ($2 million) of fines and late payment interest.

Other risks and commitments
In order to meet the medium and long-term demand of natural gas, in particular in the Italian market, Eni entered into long-term purchase contracts with producing countries. Specifically, following the strategic agreement with Gazprom signed on November 14, 2006, effective from February 1, 2007, Eni extended the duration of its gas supply contracts with Gazprom until 2035, bringing the residual average life of its supply portfolio to approximately 23 years. Existing contracts, which in general contain take-or-pay clauses, will ensure a total of approximately 62.4 bcm/y of natural gas by 2010.

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Despite the fact that an increasing portion of natural gas volumes purchased under such contracts has been sold outside Italy, management believes that in the long term, unfavorable trends in the Italian demand and supply for natural gas, also due to the possible implementation of all publicy announced plans for the construction of new supply infrastructure, and the evolution of Italian regulations of the natural gas sector, represent risk factors to the fullfilment of Eni's obligations in connection with its take-or-pay supply contracts.
Parent company guarantees given relating to contractual commitments for hydrocarbon exploration and production activities, quantified on the basis of the capital expenditures to be made, amount to euro 4,911 million (euro 5,052 million at December 31, 2005).
With effective date April 1, 2006, the Venezuelan State oil company Petróleos de Venezuela SA (PDVSA) unilaterally terminated the Operating Service Agreement (OSA) governing activities at the Dación oil field where Eni acted as a contractor, holding a 100% working interest. As a consequence, starting on the same day, operations at the Dación oil field are conducted by PDVSA. Eni proposed to PDVSA to agree on terms in order to recover the fair value of its Dación assets. On November 2006, Eni commenced proceeding before an International Centre for Settlement of Investment Disputes (ICSID) Tribunal (i.e., a tribunal acting under the auspices of the ICSID Convention and being competent pursuant to the Treaty) to claim its rights. In fact, a bilateral investments treaty is in place between The Netherlands and Venezuela (the "Treaty"). Despite this action, Eni is still ready to negotiate a solution with PDVSA to obtain a fair compensation for its assets. Based on the opinion of its legal consultants, Eni believes to be entitled to a compensation for such expropriation in an amount equal to the market value of the OSA before the expropriation took place. The market value of the OSA depends upon its expected profits. In accordance with established international practice, Eni has calculated the OSA’s market value using the discounted cash flow method, based on Eni’s interest in the expected future hydrocarbon production and associated capital expenditures and operating costs, and applying to the projected cash flow a discount rate reflecting Eni’s cost of capital as well as the specific risk of concerned activities. Independent evaluations carried out by a primary petroleum consulting firm fully support Eni’s internal evaluation. The estimated net present value of Eni’s interest in the Dación field, as calculated by Eni, is higher than the net book value of the Dación assets amounting to $829 million (equal to euro 629 million based on the EUR/US$ exchange rate as of December 31, 2006) which consequently have not been impaired. In accordance with the ICSID Convention, a judgement by the ICSID Tribunal awarding compensation to Eni would be binding upon the parties and immediately enforceable as if it were a final judgement of a court of each of the States that have ratified the ICSID Convention. The ICSID Convention was ratified in 143 States. Accordingly, if Venezuela fails to comply with the award and to pay the compensation, Eni could take steps to enforce the award against commercial assets of the Venezuelan Government almost anywhere those may be located (subject to national law provisions on sovereign immunity). In 2005 and 2006, oil production from the Dación field averaged approximately 60 kbbl/d and booked reserves at December 31, 2005 amounted to 175 million of barrels.
Under the convention signed on October 15, 1991 by TAV SpA and CEPAV Due, Eni committed to guarantee the execution of design and construction of the works assigned to the CEPAV Consortium (to which it is a party) and guaranteed to TAV the correct and timely execution of all obligations indicated in the convention in a subsequent integration deed and in any further addendum or change or integration to the same. The regulation of CEPAV Due contains the same obligations and guarantees contained in the CEPAV Uno agreement.
A guarantee for euro 253 million to Cameron LNG provided on behalf of Eni USA Gas Marketing Llc (Eni Petroleum Co Inc’s interest 100%) for the regasification contract entered into on August 1, 2005. This guarantee is subject to a suspension clause and will come into force when the regasification service starts in a period included between October 1, 2008 and June 30, 2009.
Non-quantifiable risks related to contractual assurances given to acquirers of investments against certain unforeseeable liabilities attributable to tax, state welfare contributions and environmental matters applicable to periods during which such investments were owned by Eni. Eni believes such matters will not have a material adverse effect on its Consolidated Financial Statements.

Assets under concession arrangements
Eni operates under concession arrangements mainly in the Exploration & Production segment and in some activities of the Gas & Power segment and the Refining & Marketing segment. In the Exploration & Production segment contractual clauses governing mineral concessions, licenses and exploration permits regulate the access of Eni to hydrocarbon reserves. Such clauses can differ in each country. In particular, mineral concessions, licenses and permits are granted by the legal owners and, generally, entered into with government entities, State oil companies and, in some legal contexts, private owners. As a compensation for mineral concessions, Eni pays royalties and taxes in accordance with local tax legislation. Eni sustains all the operation risks and costs related to the production and development activities and is entitled to the productions realized. In Product Sharing Agreements and in buy-back contracts, realized productions are defined on the basis of contractual agreements drawn up with State oil companies which hold the concessions. Such contractual agreements regulate the recovery of costs incurred for the exploration, development and operating activities (cost oil) and give entitlement to the own portion of the realized productions (profit oil). With reference to natural gas storage in Italy, the activity is conducted on the basis of concessions with a duration that

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does not exceed a twenty years length and it is granted by the Ministry of Productive Activities to subjects that comply with legislation requirements and that can demonstrate to be able to conduct a storage program that meets the public interest in accordance with applicable laws. In the Gas & Power segment the gas distribution activity is primarily conducted on the basis of concessions granted by local public entities. At the expiry date of the concession, a compensation is provided, defined by using criteria of business appraisal, to the outgoing operator following the sale of its own gas distribution network. Service tariffs for distribution are defined on the basis of a method established by the Authority for Electricity and Gas. Legislative Decree No. 164/2000 provides the granting of distribution services exclusively by tender, with a maximum lenght of 12 years. In the Refining & Marketing segment several service stations and other auxiliary assets of the distribution service are located in the motorway areas and they are granted by the motorway concession operators following a public tender for the sub-concession of the supplying of oil products distribution service and other auxiliary services. Such assets are amortized over the length of the concession (generally, 5 years for Italy). In exchange of the granting of the services described above, Eni provides to the motorway companies fixed and variable royalties on the basis of quantities sold. At the end of the concession period, the uncharged devolution of non-removable assets is generally provided.

Environmental regulations
Together with other companies in the industries in which it operates, Eni is subject to numerous EU, national, regional and local environmental laws and regulations concerning its oil and gas operations, products and other activities, including legislation that implements international conventions or protocols. In particular, these laws and regulations require the acquisition of a permit before drilling for hydrocarbons may commence, restrict the types, quantities and concentration of various substances that can be released into the environment in connection with exploration, drilling and production activities, limit or prohibit drilling activities on certain protected areas, and impose criminal or civil liabilities for pollution resulting from oil, natural gas, refining and petrochemical operations. These laws and regulations may also restrict emissions and discharges to surface and subsurface water resulting from the operation of natural gas processing plants, petrochemicals plants, refineries, pipeline systems and other facilities that Eni owns. In addition, Eni’s operations are subject to laws and regulations relating to the generation, handling, transportation, storage, disposal and treatment of waste materials. Environmental laws and regulations have a substantial impact on Eni’s operations. Some risk of environmental costs and liabilities is inherent in particular operations and products of Eni, as it is with other companies engaged in similar businesses, and there can be no assurance that material costs and liabilities will not be incurred. Although management, considering the actions already taken with the insurance policies to cover environmental risks and the provision for risks accrued, does not currently expect any material adverse effect upon Eni’s consolidated financial statements as a result of its compliance with such laws and regulations, there can be no assurance that there will not be a material adverse impact on Eni’s consolidated financial statements due to: (i) the possibility of as yet unknown contamination; (ii) the results of the ongoing surveys and the other possible effects of statements required by Decree No. 471/1999 of the Ministry of the Environment; (iii) the possible effect of future environmental legislation and rules; (iv) the effect of possible technological changes relating to future remediation; (v) the possibility of litigation and the difficulty of determining Eni’s liability, if any, as against other potentially responsible parties with respect to such litigation and the possible insurance recoveries.

Emission trading
Legislative Decree No. 216 of April 4, 2006 implemented the Emission Trading Directive 2003/87/EC concerning greenhouse gas emissions and Directive 2004/101/EC concerning the use of carbon credits deriving from projects for the reduction of emissions based on the flexible mechanisms devised by the Kyoto Protocol. This European emission trading scheme has been in force since January 1, 2005, and on this matter, on February 24, 2006, the Ministry of the Environment published a decree defining emission permits for the 2005-2007 period. In particular, Eni was assigned permits corresponding to 65.2 million tonnes of carbon dioxide (of which 22.4 for 2005, 21.4 for 2006 and 21.4 for 2007). Following the realization of projects for the reduction of emissions, in particular related to the cogeneration of electricity and steam through high efficiency combined cycles in refineries and petrochemical sites, emissions of carbon dioxide from Eni’s plants were lower than permits assigned in 2006.

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26 Revenues
The following is a summary of the main components of "Revenues". More information about changes in revenues is included in the "Financial review" of the "Report of the Directors".
Net sales from operations are as follows:

(million euro)  

2005

 

2006

   
 
Net sales from operations   73,679     85,957  
Change in contract work in progress   49     148  
    73,728     86,105  
   

 

Net sales from operations are net of the following items:

(million euro)  

2005

 

2006

   
 
Excise tax   14,140     13,762  
Exchanges of oil sales (excluding excise tax)   2,487     2,750  
Exchanges of other products   108     127  
Sales to service station managers for sales billed to holders of credit card   1,326     1,453  
Services billed to joint venture partners   1,331     1,385  
    19,392     19,477  
   

 

Net sales from operations by industry segment and geographic area of destination are presented in Note 32 - Information by industry segment and geographic financial information.

Other income and revenues
Other income and revenues are as follows:

(million euro)  

2005

 

2006

   
 
Gains from sale of assets   71     100  
Lease and rental income   102     98  
Contract penalties and other trade revenues   114     61  
Compensation for damages   89     40  
Other proceeds (*)   422     484  
    798     783  
   

 

     
(*)   Each individual amount included herein does not exceed euro 25 million.



27 Operating expenses

The following is a summary of the main components of "Operating expenses". More information about changes in operating expenses is included in the "Financial review" of the "Report of the Directors".

Purchases, services and other
Purchases, services and other include the following:

(million euro)  

2005

 

2006

   
 
Production costs - raw, ancillary and consumable materials and goods   35,318     44,661  
Production costs - services   9,405     10,015  
Operating leases and other   1,929     1,903  
Net provisions for contingencies   1,643     767  
Other expenses   1,100     1,089  
    49,395     58,435  
less:            
- capitalized direct costs associated with self-constructed assets - tangible assets   (704 )   (809 )
- capitalized direct costs associated with self-constructed assets - intangible assets   (124 )   (136 )
    48,567     57,490  
   

 

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Production costs - services include brokerage fees for euro 39 million (euro 24 million at 2005).
Costs for research and development that do not meet the requirements to be capitalized amount to euro 219 million (euro 202 million in 2005).

Operating leases and other for euro 1,903 million (euro 1,929 million at December 31, 2005) include operating leases for euro 860 million (euro 777 million at December 31, 2005) and royalties on hydrocarbons extracted for euro 823 million (euro 965 million in 2005). Future minimum lease payments expected to be received under non-cancellable operating leases are as follows:

(million euro)  

2006

   
To be paid:      
whithin 1 year   594  
between 2 and 5 years   1,474  
beyond 5 years   762  
    2,830  
   

Operating leases at December 31, 2006 primarily concern time charter and long-term rentals, lands, service stations and office buildings. Such leases do not include renewal options. There are no significant restrictions on operating leases imposed to Eni for dividend distribution, availability of assets and possibility to assume additional debt.

Provisions for contingencies are net of deductions not corresponding to cash expenditures of euro 767 million (euro 1,643 million at December 31, 2005) and concern in particular provisions for environmental risks for euro 248 million (euro 515 million in the 2005), provisions for contract penalties and disputes for euro 149 million (euro 336 million in the 2005), provisions for onerous contracts for euro 55 million (euro 71 million at December 31, 2005) and provisions for prize promotion for euro 44 million (euro 50 million at December 31, 2005). More information is included in Note 20 - Provisions for contingencies.

Payroll and related costs
Payroll and related costs are as follows:

(million euro)  

2005

 

2006

   
 
Wages and salaries   2,484     2,630  
Social security contributions   662     691  
Cost related to defined benefits plans and defined contributions plans   126     230  
Other costs   255     305  
    3,527     3,856  
less:            
- capitalized direct costs associated with self-constructed assets - tangible assets   (143 )   (161 )
- capitalized direct costs associated with self-constructed assets - intangible assets   (33 )   (45 )
    3,351     3,650  
   

 

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Costs related to defined benefits plans are described in Note 21 - Provisions for employee benefits.
The average number of employees of the companies included in the scope of consolidation by type was as follows:

(units)  

2005

 

2006

   
 
Senior managers   1,754     1,676  
Junior managers   10,747     11,142  
Employees   34,457     34,671  
Workers   24,345     25,426  
    71,303     72,915  
   

 

The average number of employees is calculated as half of the total of the number of employees at the beginning and end of the period. The average number of senior managers includes managers employed and operating in foreign countries, whose position is comparable to a senior manager status.

Stock compensation

STOCK GRANTS
With the aim of improving motivation and loyalty of the managers of Eni SpA and its subsidiaries as defined in Article 2359 of the Civil Code7, linking compensation to the attainment of preset individual and corporate objectives, making management participate in corporate risk and motivating them towards the creation of shareholder value and at the same increasing time their contribution to the management of the Company, Eni offers its own shares for purchase through its buy-back program (treasury shares) for no consideration to those managers of Eni who have achieved corporate and individual objectives. Assignments vest within 45 days after the end of the third year from the date of the offer.
At December 31, 2006, a total of 1,873,600 of ordinary shares with a nominal value of euro 1 per share were outstanding and concerned the 2003 stock grant plan for a total of 2,500 shares with a fair value of euro 11.20 per share, the 2004 stock grant plan for a total of 798,700 shares with a fair value of euro 14.57 per share and the 2005 stock grant plan for a total of 1,072,400 shares with a fair value of euro 20.08 per share.
Changes in the 2003, 2004 and 2005 stock grant plans consist of the following (regarding stock grants, no exercise prices are provided for):

   

2005

 

2006

   
 
    Number of shares   Market price (a) (euro)   Number of shares   Market price (a) (euro)
   
 
 
 
Stock grants as of January 1   3,112,200     18.461   3,127,200     23.460
New rights granted   1,303,400     21.336          
Rights exercised in the period   (1,273,500 )   23.097   (1,236,400 )   23.933
Rights cancelled in the period   (14,900 )   22.390   (17,200 )   23.338
Stock grants outstanding as of December 31   3,127,200     23.460   1,873,600     25.520
of which exercisable at December 31   38,700     23.460   156,700     25.520
   

 
 

 
     
(a)   Market price relating to new rights granted, rights exercised in the period and rights cancelled in the period corresponds to the average market value (arithmetic average of official prices recorded on Mercato Telematico Azionario in the month preceding: (i) the date of the Board of Directors resolution regarding the stock grants assignment; (ii) the date on which the emission/transfer of the shares granted were recorded in the grantee’s securities account; (iii) the date of the unilateral termination of employment for rights cancelled), weighted with the number of shares. Market price of stock grants at the beginning and end of the year is the price recorded at December 31.

STOCK OPTIONS
With the aim of improving motivation and loyalty of the managers of Eni SpA and its subsidiaries as defined in Article 2359 of the Civil Code8 that hold significant positions of managerial responsibility or that are considered strategic managers for the Group, Eni approved stock compensation plans that provide the assignment for no consideration of rights to purchase Eni treasury shares (options).


     
(7)   Does not include listed subsidiaries, which have their own stock grant plans.
(8)   Does not include listed subsidiaries, which have their own stock grant plans.

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2002-2004 AND 2005 PLANS
Stock options provide the right to purchase treasury shares with a 1 to 1 ratio after the end of the third year from the date ofthe grant (vesting period) and for a maximum period of five years, with a price calculated as the arithmetic average of official prices registered on the Mercato Telematico Azionario in the month preceding assignment or (starting from 2003), if greater, as the average cost of treasury shares registered in the day preceding the assignment (strike price).

2006-2008 PLAN
The 2006-2008 stock option plan introduced a performance condition for the exercise of the options. At the end of each three-year period (vesting period) from the assignment, the Board of Directors will determine a number of exercisable options, at a rate included between 0 and 100, in relation to the Total Shareholders’ Return (TSR) of Eni’s shares compared to the TSR of the six largest international oil companies for capitalization. Options can be exercised after three years from the date of the grant (vesting period) and for a maximum period of three years, with a price calculated as the arithmetic average of official prices registered on the Mercato Telematico Azionario in the month preceding the assignment (strike price).
The arithmetic average of such prices, weighted with the number of shares assigned, amounts to euro 23.119 per share.

At December 31, 2006, a total of 15,290,400 options were offered for the purchase of 15,290,400 Eni SpA ordinary shares at a nominal value of euro 1. Options refer to the 2002 stock plan for 238,000 shares with an exercise price of euro 15.216 per share, to the 2003 stock plan for 779,900 shares with an exercise price of euro 13.743 per share, to the 2004 stock plan for 3,108,500 shares with an exercise price of euro 16.576 per share, to the 2005 stock plan for 4,184,000 shares with an exercise price of euro 22.512 per share and to the 2006 stock plan for 6,980,000 shares with an exercise price of euro 23.119 euro per share.
At December 31, 2006 the weighted-average remaining contractual life of the plans at December 2002, 2003, 2004, 2005 and 2006 was 3 years and 7 months, 4 years and 7 months, 5 years and 7 months, 6 years and 7 months and 5 years and 7 months, respectively.
Changes in stock option plans in 2005 and 2006 consist of the following:

   

2005

 

2006

   
 
    Number of shares   Weighted average exercise price (euro)   Market price (a) (euro)   Number of shares   Weighted average exercise price (euro)   Market price (a) (euro)
   
 
 
 
 
 
Options as of January 1   11,789,000     15.111   18.461   13,379,600     17.705   23.460
New options granted   4,818,500     22.512   22.512   7,050,000     23.119   23.119
Options exercised in the period   (3,106,400 )   15.364   22.485   (4,943,200 )   15.111   23.511
Options cancelled in the period   (121,500 )   16.530   23.100   (196,000 )   19.119   23.797
Options outstanding as of December 31   13,379,600     17.705   23.460   15,290,400     21.022   25.520
of which exercisable at December 31   1,540,600     16.104   23.460   1,622,900     16.190   25.520
   

 
 
 

 
 
     
(a)   Market price relating to new rights granted, rights exercised in the period and rights cancelled in the period corresponds to the average market value (arithmetic average of official prices recorded on Mercato Telematico Azionario in the month preceding: (i) the date of the Board of Directors resolution regarding the stock grants assignment; (ii) the date in which the emission/transfer of the shares granted was recorded in the grantee’s securities account; (iii) the date in which the unilateral termination of employment for rights was cancelled, weighted with the number of shares. Market price of stock grants at the beginning and end of the year is the price recorded at December 31.

The fair value of stock options granted during the years 2002, 2003, 2004, 2005 and 2006 was euro 5.39, euro 1.50, euro 2.01, euro 3.33 respectively, and the weighted average of euro 2.89 per share was calculated applying the following assumptions:

        2002   2003   2004   2005   2006
       
 
 
 
 
Risk-free interest rate   (%)   3.5   3.2   3.2   2.5   4.0
Expected life   (years)   8   8   8   8   6
Expected volatility   (%)   43   22   19   21   17
Expected dividends   (%)   4.5   5.4   4.5   4.0   5.3
       
 
 
 
 

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Compensation of key management personnel
Compensation of persons responsible for key positions in planning, direction and control functions of Eni Group companies, including executive and non-executive officers, general managers and manager with strategic responsibility (key management personnel) amounted to euro 15 and euro 23 million for 2005 and 2006, respectively, and consisted of the following:

(million euro)  

2005

 

2006

   
 
Wages and salaries   11     16  
Post-employment benefits   1     1  
Other long term benefits         3  
Indemnities due upon termination of employment   1        
Stock grant/option   2     3  
    15     23  
   

 

Compensation of Directors, Statutory Auditors and General Managers
Compensation of Directors, Statutory Auditors and General Managers amount to euro 19.2 million and euro 8.7 million in 2005 and 2006, respectively. Compensation of Statutory Auditors amounted to euro 0.785 and euro 0.686 million in 2005 and 2006, respectively. Compensation of Directors, Statutory Auditors and General Managers include emoluments and all other salary and social security compensations due for the function of manager or statutory auditor performed by Eni SpA or other companies included in the scope of consolidation, that are a cost for Eni.

Depreciation, amortization and impairments
Depreciation, amortization and impairments consist of the following:

(million euro)  

2005

 

2006

   
 
Depreciation and amortization:            
- tangible assets   4,576     4,821  
- intangible assets   936     1,335  
    5,512     6,156  
Impairments:            
- tangible assets   264     231  
- intangible assets   8     54  
    272     285  
less:            
- direct costs associated with self-constructed assets         (17 )
- capitalized direct costs associated with self-constructed assets - tangible assets   (2 )   (2 )
- capitalized direct costs associated with self-constructed assets - intangible assets   (1 )   (1 )
    5,781     6,421  
   

 

28 Financial income (expense)
Financial income (expense) consists of the following:

(million euro)  

2005

 

2006

   
 
Income (expense) on derivatives   (386 )   383  
Net income from financial receivables   95     130  
Financial expense capitalized   159     116  
Net interest due to banks   (38 )   79  
Net income from securities   36     51  
Interest on tax credits   17     17  
Financial expense due to the passage of time (a)   (109 )   (116 )
Exchange differences, net   169     (152 )
Interest and other financial expense on ordinary bonds   (265 )   (247 )
Other financial expense, net   (44 )   (100 )
    (366 )   161  
   

 

     
(a)   The item concerns the increase in provisions for contingencies that are indicated at an actualized value in non-current liabilities.

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Income (expense) on derivatives consist of the following:

(million euro)  

2005

 

2006

   
 
Derivatives on exchange rate   (85 )   313  
Derivatives on interest rate   (138 )   61  
Derivatives on commodities   (163 )   9  
    (386 )   383  
   

 

The increase in income (expense) from derivatives of euro 769 million is primarily due to the application of IAS 39 which requires that derivatives be stated at fair value and the effects charged to the profit and loss account, instead of being connected with the economic effects of the hedged transactions. Such derivatives, in fact, do not meet the conditions required by IFRS to be qualified as hedging instruments. In addition, the decrease in net exchange differences of euro 321 million is primarily due to the application of IAS 39, due to the fact that the effect of the translation at period end of assets and liabilities denominated in currencies other than the functional currency is not compensated by the effect of the translation at period end of the commitments for derivatives contracts.


29 Income (expense) from investments

Effects of investments accounted for using the equity method
Effects of investments accounted for using the equity method consist of the following:

(million euro)  

2005

 

2006

   
 
Gains from investments accounted for using the equity method   770     887  
Losses from investments accounted for using the equity method   (33 )   (36 )
Provisions for losses         (56 )
    737     795  
   

 

More information about gains and losses from investments accounted for using the equity method is presented in Note 11 - Investments.

Other income (expense) from investments
Other income (expense) from investments consists of the following:

(million euro)  

2005

 

2006

   
 
Dividends   33     98  
Gains on disposals   179     25  
Losses on disposals   (8 )   (7 )
Other income (expense), net   (27 )   (8 )
    177     108  
   

 

Dividends of euro 98 million primarily concern Nigeria LNG Ltd (euro 56 million).
Gains on disposals of euro 25 million primarily concern the sale of Fiorentina Gas SpA and Toscana Gas SpA (euro 16 million). Gains on disposals relating to the year 2005 of euro 179 million concern the sale of 100% of the share capital of Italiana Petroli SpA (euro 132 million).

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30 Income tax expense
Income tax expense consists of the following:

(million euro)  

2005

 

2006

   
 
Current taxes:            
- Italian subsidiaries   1,872     2,007  
- foreign subsidiaries of the Exploration & Production segment   5,116     6,740  
- foreign subsidiaries   373     529  
    7,361     9,276  
Less:            
- tax credits on dividend distributions not offset with current tax payment   (34 )      
    7,327     9,276  
Net deferred taxes:            
- Italian subsidiaries   334     230  
- foreign subsidiaries of the Exploration & Production segment   464     1,095  
- foreign subsidiaries   3     (33 )
    801     1,292  
    8,128     10,568  
   

 

Current taxes of the year relate to Italian companies for euro 2,007 million and concern Ires for euro 1,570 and Irap for euro 374 million and foreign taxes for euro 63 million.
The effective tax rate was 51.8% (46.8% in 2005) compared with a statutory tax rate of 37.9% calculated by applying a 33% tax rate (Ires) to profit before income taxes and 4.25% tax rate (Irap) to the net value of production as provided for by Italian laws.
The difference between the statutory and effective tax rate is due to the following factors:

(%)  

2005

 

2006

   
 
Statutory tax rate   38.1     37.9  
Items increasing (decreasing) statutory tax rate:            
- higher foreign subsidiaries tax rate   8.8     13.6  
- permanent differences   0.8     0.2  
- other   (0.9 )   0.1  
    8.7     13.9  
    46.8     51.8  
   

 

The increase in the tax rate of foreign subsidiaries of 4.8% essentially concerns the Eploration & Production segment (4.5%) and includes the effects deriving from the application of the windfall tax introduced by the Algerian government effective from August 1, 2006 (1.6%), a supplemental tax rate introduced by the government of the United Kingdom relating to the North Sea production effective from January 1, 2006 (1.0%) and the increase and the different allocation by country of profit before income taxes (1.9%).
Permanent differences in 2006 mainly concern the nondeductibility from taxable income of costs relating to fines of the Italian Antitrust Authority (0.4%).
Permanent differences in 2005 mainly concern the nondeductibility from taxable income of the increase in provisions for contingencies following the fine imposed on February 15, 2006 by the Italian Antitrust Authority to Eni SpA (0.6%).


31 Earnings per share
Basic earnings per share is calculated by dividing "Net profit" of the year by the weighted-average number of shares issued and outstanding during the year, excluding treasury shares.
The average number of shares used for the calculation of the basic earnings per share was 3,758,519,603 and 3,698,201,896 in 2005 and 2006, respectively.
Diluted earnings per share is calculated by dividing "Net profit" of the year by the weighted-average number of shares issued and outstanding during the year, excluding treasury shares, including shares that could be issued potentially.
At December 31, 2005 and December 31, 2006, shares that could be issued potentially concern essentially shares granted under stock grant and stock option plans. The average number of shares used for the calculation of the diluted earnings per share was 3,763,375,140 and 3,701,262,557 in 2005 and 2006, respectively.

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Reconciliation of the average number of shares used for the calculation of the basic and diluted earning per share is as follows:

(million euro)  

2005

 

2006

   
 
Average number of shares used for the calculation of the basic earnings per share       3,758,519,603   3,698,201,896
Number of potential shares following stock grant plans       2,268,265   1,070,676
Number of potential shares following stock options plans       2,587,272   1,989,985
Average number of shares used for the calculation of the diluted earnings per share       3,763,375,140   3,701,262,557
Eni’s net profit   (million euro)   8,788   9,217
Basic earning per share   (euro per share)   2.34   2.49
Diluted earning per share   (euro per share)   2.34   2.49
       
 

 

32 Information by industry segment and geographic financial information

Information by industry segment9

(million euro)

 

Exploration & Production

 

Gas & Power

 

Refining & Marketing

 

Petrochemicals

 

Engineering & Construction

 

Other activities

 

Corporate and financial companies

 

Elimination

 

Total

   
 
 
 
 
 
 
 
 
2005                                                      
Net sales from operations (a)   22,531     22,969     33,732     6,255     5,733     863     1,239              
Less: intersegment sales   (14,761 )   (572 )   (1,092 )   (683 )   (925 )   (546 )   (1,015 )            
Net sales to customers   7,770     22,397     32,640     5,572     4,808     317     224           73,728  
Operating profit   12,592     3,321     1,857     202     307     (934 )   (377 )   (141 )   16,827  
Provisions for contingencies   50     703     420     47     32     284     107           1,643  
Depreciation, amortization and writedowns   4,101     685     467     147     180     91     114     (4 )   5,781  
Effects of investments accounted for using the equity method   14     359     221     3     140                       737  
Identifiable assets (b)   29,010     21,928     11,787     2,905     5,248     438     1,523     (534 )   72,305  
Investments accounted for using the equity method   292     2,155     936     19     457     31                 3,890  
Identifiable liabilities (c)   6,785     5,097     4,542     702     3,204     2,070     2,131           24,531  
Capital expenditures   4,965     1,152     656     112     349     48     132           7,414  
2006                                                      
Net sales from operations (a)   27,173     28,368     38,210     6,823     6,979     823     1,174              
Less: intersegment sales   (18,445 )   (751 )   (1,300 )   (667 )   (771 )   (520 )   (991 )            
Net sales to customers   8,728     27,617     36,910     6,156     6,208     303     183           86,105  
Operating profit   15,580     3,802     319     172     505     (622 )   (296 )   (133 )   19,327  
Provisions for contingencies   153     197     264     30     (13 )   236     (100 )         767  
Depreciation, amortization and writedowns   4,776     738     447     174     196     28     71     (9 )   6,421  
Effects of investments accounted for using the equity method   28     509     194     2     66     (4 )               795  
Identifiable assets (b)   29,720     23,500     11,359     2,984     6,362     344     1,023     (666 )   74,626  
Investments accounted for using the equity method   258     2,214     874     11     483     46                 3,886  
Identifiable liabilities (c)   9,119     5,284     4,712     806     3,869     1,940     1,619           27,349  
Capital expenditures   5,203     1,174     645     99     591     72     88     (39 )   7,833  
   

 

 

 

 

 

 

 

 

     
(a)   Before elimination of intersegment sales.
(b)   Includes assets directly related to the generation of operating profit.
(c)   Includes liabilities directly related to the generation of operating profit.

Intersegment sales are conducted on an arm’s length basis.


     
(9)   Operating profit (loss) by industry segment for 2005 have been reclassified on the basis of the new subdivision within segments. This reclassification concerns the Exploration & Production, Other activities and Corporate and financial companies segments.

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Geographic financial information

ASSETS AND INVESTMENTS BY GEOGRAPHIC AREA OF ORIGIN

(million euro)      

Italy

 

Other EU

 

Rest of Europe

 

Americas

 

Asia

 

Africa

 

Other areas

 

Total

       
 
 
 
 
 
 
 
2005                                
Identifiable assets (a)   38,229   8,768   3,085   2,670   5,864   13,445   244   72,305
Capital expenditures   2,442   545   415   507   1,181   2,233   91   7,414
2006                                
Identifiable assets (a)   37,339   10,037   3,200   2,987   6,341   14,190   532   74,626
Capital expenditures   2,529   713   436   572   1,032   2,419   132   7,833
   
 
 
 
 
 
 
 
     
(a)   Includes assets directly related to the generation of operating profit.

SALES FROM OPERATIONS BY GEOGRAPHIC AREA OF DESTINATION

(million euro)  

2005

 

2006

   
 
Italy   32,846     36,343  
Other European Union   19,601     23,949  
Rest of Europe   5,123     6,975  
Americas   6,103     6,250  
Asia   4,399     5,595  
Africa   5,259     5,949  
Other areas   397     1,044  
    73,728     86,105  
   

 

 

33 Transactions with related parties
In the ordinary course of its business, Eni enters into transactions concerning the exchange of goods, provision of services and financing with joint ventures, affiliated companies and non-consolidated subsidiaries as well as with entities directly and indirectly owned or controlled by the Government. All such transactions are mainly conducted on an arm’s length basis in the interest of Eni companies.
The following is a description of trade and financing transactions with related parties.

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Trade and other transactions
Trade and other transactions in the 2005 consisted of the following:

(million euro)  

Dec. 31, 2005

 

2005

   
 
 

Costs

 

Revenues

 
 
Name  

Receivables

 

Payables

 

Guarantees

 

Goods

 

Services

 

Goods

 

Services


 
 
 
 
 
 
 
Joint ventures and affiliated companies                            
ASG Scarl   13   66   72       173       6
Azienda Energia e Servizi Torino SpA   2   24           56       2
Bayernoil Raffineriegesellshaft mbH       49   1       814        
Bernhard Rosa Inh. Ingeborg Plöchinger GmbH   10                   172    
Blue Stream Pipeline Co BV   45   12           177       4
Bronberger & Kessler und Gilg & Schweiger GmbH   12                   207    
Cam Petroli Srl   85                   593    
CEPAV (Consorzio Eni per l’Alta Velocità) Uno   105   107   4,894               411
Eni Gas BV   16   149           47        
Eni Oil Co Ltd       84           50        
Fox Energy SpA   22           4       240    
Gruppo Distribuzione Petroli Srl   22                   89    
Karachaganak Petroleum Operating BV   13   46       6   99       4
Mangrove Gas Netherlands BV           55                
Modena Scarl   2   12   61       56   1   1
Petrobel Belayim Petroleum Co       138           248        
Promgas SpA   44   45       307       355    
Raffineria di Milazzo ScpA   10   10           204   94    
Rodano Consortile Scarl   2   20           80       2
RPCO Enterprises Ltd           55                
Supermetanol CA       8       65            
Super Octanos CA   1   14       265            
Toscana Energia Clienti SpA   46                   118    
Trans Austria Gasleitung GmbH   43   55       43   143       47
Transitgas AG       7           64        
Transmediterranean Pipeline Co Ltd       4           88       1
Unión Fenosa Gas SA   4   4   62   79       16   2
Other (*)   101   86   112   69   157   147   67
    598   940   5,312   838   2,456   2,032   547
Unconsolidated subsidiaries                            
Agip Kazakhstan North Caspian Operating Co NV   4   152       5   19       28
Eni BTC Ltd           165                
Other (*)   44   48   8   1   31   15   9
    48   200   173   6   50   15   37
    646   1,140   5,485   844   2,506   2,047   584
Entities owned or controlled by the Italian Government                            
Alitalia   20                   276    
Enel   187   5       12   10   1,180   333
Other (*)   20   19           57   103   12
    227   24       12   67   1,559   345
    873   1,164   5,485    856   2,573   3,606   929
   
 
 
 
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 50 million.

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Trade and other transactions in 2006 consisted of the following:

(million euro)  

Dec. 31, 2006

 

2006

   
 
 

Costs

 

Revenues

 
 
Name  

Receivables

 

Payables

 

Guarantees

 

Goods

 

Services

 

Goods

 

Services


 
 
 
 
 
 
 
Joint ventures and affiliated companies                            
ASG Scarl   7   40   80       88   1   1
Azienda Energia e Servizi Torino SpA   1   22           64   1   1
Bernhard Rosa Inh. Ingeborg Plöchinger GmbH   10                   96    
Blue Stream Pipeline Co BV   34   19           193       1
Bronberger & Kessler und Gilg & Schweiger GmbH   11                   113    
Cam Petroli Srl   103                   310    
CEPAV (Consorzio Eni per l’Alta Velocità) Uno   87   87   5,654   16   2       304
Charville - Consultores e Serviços Lda   7       85           4   11
Eni Gas BV   28   90       7   72   8   2
Eni Oil Co Ltd   5   96           59        
Fox Energy SpA   35                   125    
Gasversorgung Süddeutschland GmbH   14               1   123   19
Gruppo Distribuzione Petroli Srl   19                   54    
Karachaganak Petroleum Operating BV   23   70       29   129       7
Mangrove Gas Netherlands BV       1   52                
Petrobel Belayim Petroleum Co       3           181        
Promgas SpA   44   39       375       419    
Raffineria di Milazzo ScpA   9   12           237   109    
Rodano Consortile Scarl   3   14           54       1
Rpco Enterprises Ltd   13       104               12
Supermetanol CA       13       91            
Super Octanos CA       13       257            
Trans Austria Gasleitung GmbH   7   78       53   138       56
Transitgas AG       8           64        
Transmediterranean Pipeline Co Ltd       7           80        
Unión Fenosa Gas SA   1   7   61   93   7        
Other (*)   72   169   168   75   188   119   66
    533   788   6,204   996   1,557   1,482   481
Unconsolidated subsidiaries                            
Agip Kazakhstan North Caspian Operating Co NV   27   132       18   16       57
Eni BTC Ltd           185                
Eni Timor Leste SpA           102                
Other (*)   20   30   8   1   4   8   4
    47   162   295   19   20   8   61
    580   950   6,499   1,015   1,577   1,490   542
Entities owned or controlled by the Italian Government                            
Alitalia   12                   354    
Enel   162   42       47   33   1,068   383
Other (*)   42   29       4   44   136   1
    216   71       51   77   1,558   384
    796   1,021   6,499   1,066   1,654   3,048   926
   
 
 
 
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 50 million.

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Engineering, construction and maintenance services are acquired on an arm’s length basis from the Cosmi Holding Group, related to Eni through a member of the Board of Directors, for a total of approximately euro 18 million and euro 13 million in 2005 and 2006, respectively.
Most significant transactions concern:

Financing transactions
Financing transactions in 2005 are as follows:

(million euro)  

Dec. 31, 2005

 

2005

   
 
Name  

Receivables

 

Payables

 

Guarantees

 

Charges

 

Gains


 
 
 
 
 
Joint ventures and affiliated companies                    
Blue Stream Pipeline Co BV       15   887        
Raffineria di Milazzo ScpA           72        
Spanish Egyptian Gas Co SAE           360        
Trans Austria Gasleitung GmbH   386               12
Transmediterranean Pipeline Co Ltd   190               11
Other (*)   74   125   81   27   47
    650   140   1,400   27   70
Unconsolidated subsidiaries                    
Other (*)   79   30   34   1   2
    79   30   34   1   2
    729   170   1,434   28   72
   
 
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 50 million.

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Financing transactions in 2006 are as follows:

(million euro)  

Dec. 31, 2006

 

2006

   
 
Name  

Receivables

 

Payables

 

Guarantees

 

Charges

 

Gains


 
 
 
 
 
Joint ventures and affiliated companies                    
Blue Stream Pipeline Co BV       3   794   4   26
Raffineria di Milazzo ScpA           57        
Spanish Egyptian Gas Co SAE           323         
Trans Austria Gasleitung GmbH   41               6
Transmediterranean Pipeline Co Ltd   147               11
Other (*)   88   81   39   13   11
    276   84   1,213   17   54
Unconsolidated subsidiaries                    
Other (*)   95   25   2   1   4
    95   25   2   1   4
    371   109   1,215   18   58
   
 
 
 
 
     
(*)   Each individual amount included herein does not exceed euro 50 million.

Most significant transactions in 2006 included:

Impact of transactions and positions with related parties on the balance sheet, net profit and cash flows
The impact of transactions and positions with related parties on the balance sheet, net profit and financial flows consists of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 
(million euro)   Total   Related parties   Impact %   Total   Related parties   Impact %
   
 
 
 
 
 
Trade and other receivables   17,902     1,344     7.51     18,799     1,027     5.46  
Other current assets   369                 855     4     0.47  
Other non-current financial assets   1,050     258     24.57     805     136     16.89  
Current financial liabilities   4,612     152     3.30     3,400     92     2.71  
Trade and other payables   13,095     1,164     8.89     15,995     961     6.01  
Other liabilities   613                 634     4     0.63  
Long-term debt and current portion of long-term debt   8,386     18     0.21     8,299     17     0.20  
Other non-current liabilities   897                 418     56     13.40  
   

 

 

 

 

 

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The impact of transactions with related parties on the profit and loss accounts consists of the following:

   

Dec. 31, 2005

 

Dec. 31, 2006

   
 
(million euro)   Total   Related parties   Impact %   Total   Related parties   Impact %
   
 
 
 
 
 
Net sales from operations   73,728     4,535     6.15     86,105     3,974     4.62  
Purchases, services and other   48,567     3,429     7.06     57,490     2,720     4.73  
Financial income   3,131     72     2.30     4,132     58     1.40  
Financial expense   3,497     28     0.80     3,971     18     0.45  
   

 

 

 

 

 

Transactions with related parties concern the ordinary course of Eni’s business and are mainly conducted on an arm’s length basis.
Main cash flows with related parties are as follows:

(million euro)  

2005

 

2006

   
 
Revenues and other income   4,535     3,974  
Costs and other expenses   (3,429 )   (2,720 )
Net change in trade and other receivables and payables   (221 )   162  
Dividends and net interests   345     790  
Net cash provided from operating activities   1,230     2,206  
Capital expenditures in tangible and intangible assets   (474 )   (733 )
Investments   (30 )   (20 )
Change in accounts payable in relation to investments   342     (276 )
Change in financial receivables   2     343  
Net cash used in investing activities   (160 )   (686 )
Change in financial liabilities   23     (57 )
Net cash used in financing activities   23     (57 )
Total financial flows to related parties   1,093     1,463  
   

 

The impact of cash flows with related parties consists of the following:

   

2005

 

2006

   
 
(million euro)   Total   Related parties   Impact %   Total   Related parties   Impact %
   
 
 
 
 
 
Cash provided from operating activities   14,936     1,230     8.24     17,001     2,206     12.98  
Cash used in investing activities   (6,815 )   (160 )   2.35     (7,051 )   (686 )   9.73  
Cash used in financing activities   (7,824 )   23     ..     (7,097 )   (57 )   0.80  
   

 

 

 

 

 

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34 Significant non recurring events and operations
Non recurring charges consist of the following:

(million euro)  

2005

 

2006

   
 
Italian Antitrust fines   (290 )   (184 )
Italian Authority for Electricity and Gas fines         (55 )
    (290 )   (239 )
   

 

The Italian Antitrust fines of 2006 consist of: (i) a fine imposed by the Italian Antitrust Authority following the proceeding on supplies of jet fuel (euro 109 million); (ii) inquiries concerning alleged anti-competitive agreements in the area of elastomers (euro 75 million). The fine imposed by the Authority for Electricity and Gas concerns an inquiry relating to the use of storage capacity in thermal year 2005-2006 (euro 45 million) and an inquiry relating to an information requirement on natural gas supplying prices (euro 10 million). The antitrust fine for 2005 concerns a fine imposed by the Italian Antitrust Authority on February 15, 2006 relating to an abuse of dominant position following the behaviors of Trans Tunisian Pipeline Co Ltd (TTPC). More information is included in Note 25 - Guarantees, commitments and risks - Legal proceedings - Antitrust - TTPC.


35 Positions or transactions deriving from atypical and/or unusual operations
In 2005 and in 2006 no positions or transactions deriving from atypical and/or unusual operations were reported.

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36 Adjustment of the Consolidated Financial Statements to U.S. GAAP
As its shares are listed on the New York Stock Exchange, Eni files an Annual Report (Form 20-F) with the Securities and Exchange Commission (SEC). The Annual Report (Form 20-F) includes the adjustment of the Consolidated Financial Statements to U.S. GAAP. The following information is necessary to reconcile the Italian consolidated annual report for 2006 to generally accepted accounting principles in the United States (U.S. GAAP).

Summary of significant differences between IFRS and U.S. GAAP
Eni’s Financial Statements at December 31, 2006 have been prepared in accordance with International Financial Reporting Standards (IFRS)10 adopted by the European Commission, which differ in certain aspects from U.S. GAAP. A description of the significant differences and their effects on net profit and shareholders’ equity is set forth in the following notes.

A) CONSOLIDATION POLICY
Eni’s consolidation policy is described under "Principles of consolidation" of the Notes to the Consolidated Financial Statements. In particular, under IFRS, the consolidated financial statements include also companies in which Eni holds less than 50% of the voting rights, but over which it exercises control in shareholders’ meetings.
Under U.S. GAAP, investments of less than 50% are accounted for by applying the equity method. Under U.S. GAAP, Saipem SpA and its subsidiaries are excluded from consolidation and are accounted for under the equity method. Under IFRS, Eni exercises control of Saipem SpA also without holding the majority of voting rights (43.54%) exercisable in shareholders' meetings. During 2006 Saipem Projects SpA (100% Saipem SpA) acquired from Eni SpA 100% of Snamprogetti SpA that, as a result, has been excluded from consolidation; for U.S. GAAP purposes the gain on this sale was recognized in the profit and loss account.

B) EXPLORATION & PRODUCTION ACTIVITIES

Exploration
Consistent with IFRS, the international specific criteria have been applied for hydrocarbons exploration and production activities. In particular, exploration costs, including successful exploratory wells, are recorded as intangible assets and are amortized in full in the period incurred (i.e., expensed as incurred for financial reporting purposes). Costs for the acquisition of exploration permits and for the extension of existing permits, are capitalized and amortized over the expected period of benefit.
Under U.S. GAAP, costs relating to exploratory wells are initially capitalized as "incomplete wells and other" until it is determined if commercial quantities of reserves have been discovered ("successful efforts method"). After completion of drilling and evaluation of the well, the capitalized costs are either charged to expense or reclassified as part of Eni’s proved mineral interests. Costs of exploratory wells that have found commercially producible quantities of reserves that cannot be classified as proved remain capitalized after the completion of drilling if: (i) such wells have found a sufficient quantity of reserves to justify completion as a producing wells; (ii) the enterprise is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if an enterprise obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well is assumed to be impaired, and its costs, net of any salvage value, are charged to expense. Capitalized well costs related to proved properties are amortized over proved developed reserves on the basis of units of production. Other exploration costs, including geological and geophysical surveys, are expensed when incurred.

Development
Development costs are those costs incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering and storing oil and gas. Costs to operate and maintain wells and field equipment are expensed as incurred.
Under IFRS, costs of unsuccessful development wells are expensed immediately as loss on disposal. Costs of successful development wells are capitalized and amortized using the unit-of-production method.
Under U.S. GAAP, costs of productive wells and development dry holes, both tangible and intangible, are capitalized and amortized using the unit-of-production method.

C) VALUATION OF ASSETS AND SUBSEQUENT REVALUATION
Both IFRS and U.S. GAAP require that recoverability of carrying value of tangible and intangible assets with a definite useful life is checked using similar criteria, with the exception of the following aspects.
Under IFRS, in order to determine whether an impairment exists, the book value of an asset is compared with its recoverable amount which is represented by the greater of fair value, net of disposal costs and value in use which is calculated by


     
(10)   There are no relevant differences between the accounting principles approved by the European Commission and the ones issued by IASB.

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discounting estimated cash flows arising from the use of the asset and its sale at the end of its useful life. Impairment losses of assets different from goodwill are reversed when the situation giving rise to an impairment ceases to exist.
Under U.S. GAAP, the recoverability of the value of an asset used in the production process is first checked by comparing the carrying amount with the sum of undiscounted cash flows expected from use of the asset and its disposal at the end of its useful life. Only if the result of this first check is negative does the entity write the asset down using discounted future cash flows. Under U.S. GAAP reversals of impairment losses are not permitted.

D) DEFERRED TAX ASSETS AND LIABILITIES
Under IFRS, taxes payable relating to certain potential distributions from shareholders’ equity or upon liquidation of a company are accrued only to the extent such distributions are planned.
Under U.S. GAAP, deferred tax liabilities are recognized regardless of expected distribution of dividends or the disposal of investments. However, U.S. GAAP does not require the accrual of deferred taxes when the investment is a foreign subsidiary and there is sufficient evidence that profits will remain permanently invested in the entity.
The adjustment included in Note 37 - Reconciliation of net profit and shareholders’ equity determined under IFRS to U.S. GAAP, concerns the recognition of deferred taxes on shareholders’ equity regardless of its expected distribution and it is measured taking into account the exception provided for foreign subsidiaries. This adjustment includes also deferred tax assets and liabilities on other adjustments to U.S. GAAP.

E) INTANGIBLE ASSETS
Under U.S. GAAP, intangible assets include the recording, separately from goodwill, of assets acquired in or following business combinations arising from legal or contractual rights regardless of their ability to be transferred and of other assets owned by the entity that can be transferred individually or together with other assets and liabilities. If such intangible assets have definite lives they are amortized by the straight line method over their useful lives.
IFRS are consistent with U.S. GAAP. However, considering that in the first application of IFRS, Eni has decided not to restate business combinations, the value of the intangible assets described is recorded in the item "Goodwill".
Both under U.S. GAAP and IFRS, goodwill and intangible assets with an indefinite useful life are not amortized; these assets are subject to a yearly evaluation in order to define the relevant impairment if needed. Such accounting principles have been adopted starting from January 1, 2002 for U.S. GAAP and January 1, 2004 for IFRS. The adjustments for the reconciliation of shareholders' equity included in Note 37 - Reconciliation of net profit and shareholders’ equity determined under IFRS to U.S. GAAP, concern the reversal of the amortization of goodwill for the years 2002 and 2003.

F) INVENTORIES
Under U.S. GAAP, crude oil, petroleum products and natural gas inventories are calculated using the LIFO method.
Under IFRS the LIFO method is not permitted.

G) PROVISIONS FOR EMPLOYEE BENEFITS
Both under U.S. GAAP and IFRS liabilities related to defined benefit plans and long-term employee benefits are determined by adopting actuarial assumptions. The application of the corridor approach is allowed. Under the corridor approach the actuarial gains and losses of defined benefit plans, deriving from a change in the actuarial assumptions used or from a change in the conditions of the plan, are charged to the profit and loss account, proportionally through the residual average working life of the employees participating to the plan, in the limits of the share of the discounted profit/loss not charged beforehand, that exceeds the greater of 10% of liabilities and 10% of the fair value of the plan assets.
Under IFRS, following the application of the corridor approach, the liability for employee benefits is recognised in the caption "Provisions for employee benefits" and excludes actuarial incomes and losses not charged to the profit and loss account. Plan assets are measured on the basis of their expected return.
Under U.S. GAAP plan assets are measured on the basis of their effective return. The actuarial liability recognized in the balance sheet includes the total amount of incomes and losses deriving from changes in actuarial assumptions; changes of liabilities relating to actuarial incomes and losses not accounted in the profit and loss account are recognized, net of the related deferred tax effect with a corresponding entry to the item of the shareholders’ equity "Other comprehensive income".11 In the following periods, the actuarial incomes and losses "suspended" in other comprehensive income are recognised in the profit and loss account according to the corridor method.


     
(11)   The difference between IFRS and U.S. GAAP takes into consideration the adoption of SFAS 158 “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans - an amendment of FASB Statements No. 87, 88, 106, and 132(R)” (SFAS 158); the effects of the adoption of SFAS 158 are described in the paragraph “Changes in accounting principles”.

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37 Reconciliation of net profit and shareholders’ equity determined under IFRS to U.S. GAAP
The following is a summary of the significant adjustments to net profit of 2004, 2005 and 2006 and to shareholders’ equity as of December 31, 2005 and as of December 31, 2006 that would be required if U.S. GAAP had been applied instead of IFRS in the Consolidated Financial Statements.

(million euro)   2004  

2005

 

2006

   
 
 
Net profit pertaining to Eni according to the Financial Statements prepared under IFRS   7,059     8,788     9,217  
Items increasing (decreasing) reported net profit:                  
A. effect of the differences related to companies consolidated under IFRS but carried at the equity method under U.S. GAAP   (1 )         (1 )
B. successful-efforts accounting   (82 )   47     359  
C. elimination of assets impairments and revaluations   5           36  
D. deferred income taxes   (21 )   (279 )   (120 )
E. assets associated to the acquisition of a company (portfolio of clients)   (5 )   (5 )   (5 )
F. valuation of inventories   (316 )   (956 )   267  
Gain on sale of Snamprogetti SpA to Saipem Projects SpA               252  
Effect of the difference between IFRS and U.S. GAAP on investments accounted for using the equity method   34     12     1  
Other adjustments   (280 )   (3 )   (4 )
Effect of U.S. GAAP adjustments on minority interest (a)   8     (21 )   3  
Net adjustment   (658 )   (1,205 )   788  
Net profit in accordance with U.S. GAAP   6,401     7,583     10,005  
Basic profit per share (b)   1.70     2.02     2.71  
Diluted profit per share (b)   1.70     2.01     2.70  
Basic profit per ADS (based on two shares per ADS) (b)   3.39     4.03     5.41  
Diluted profit per ADS (based on two shares per ADS) (b)   3.39     4.03     5.41  
   

 

 

     
(a)   Adjustment to account for minority interest portion of differences A through F, which include 100% of differences between IFRS and U.S. GAAP on less than wholly-owned subsidiaries.
(b)   Amounts in euro.

 

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Shareholders’ equity pertaining to Eni according to the Financial Statements prepared under IFRS   36,868     39,029  
Items increasing (decreasing) reported shareholders’ equity (a):            
A. effect of the differences related to companies consolidated under IFRS but carried at the equity method under U.S. GAAP   37     33  
B. successful-efforts accounting   2,504     2,672  
C. elimination of assets impairments and revaluations   230     311  
D. deferred income taxes   (3,415 )   (3,495 )
E. goodwill   811     786  
E. assets associated with the acquisition of a company (portfolio of clients)   (16 )   (22 )
F. valuation of inventories   (2,036 )   (1,769 )
G. provisions for employees benefits         (32 )
Effect of the difference between IFRS and U.S. GAAP on investments accounted for using the equity method   173     169  
Other adjustments         2  
Effect of U.S. GAAP adjustments on minority interest (b)   (31 )   (28 )
Net adjustment   (1,743 )   (1,373 )
Shareholders’ equity in accordance with U.S. GAAP   35,125     37,656  
   

 

     
(a)   Items increasing (decreasing) reported shareholders’ equity of foreign companies are translated into euro at the exchange rate prevailing at the end of each period.
(b)   Adjustment to account for minority interest portion of differences A through G, which include 100% of differences between IFRS and U.S. GAAP on less than wholly-owned subsidiaries.

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The consolidated balance sheets, if determined under U.S. GAAP would have been as follows:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
ASSETS            
Current assets            
Cash and cash equivalent   1,121     3,685  
Other financial assets for trading or available for sale   1,484     970  
Trade and other receivables   17,971     18,568  
Inventories   1,929     2,721  
Current tax assets   575     447  
Other current assets   387     877  
Total current assets   23,467     27,268  
Non-current assets            
Property, plant and equipment   43,868     42,924  
Other assets         629  
Inventories - compulsory stock   1,462     1,273  
Intangible assets   5,244     6,057  
Investments accounted for using the equity method   4,589     4,305  
Other investments   416     353  
Other financial assets   1,105     860  
Deferred tax assets   1,847     1,145  
Other non-current receivables   979     992  
Total non-current assets   59,510     58,538  
TOTAL ASSETS   82,977     85,806  
LIABILITIES AND SHAREHOLDERS’ EQUITY            
Current liabilities            
Current financial liabilities   4,916     4,032  
Current portion of long-term debt   809     890  
Trade and other payables   11,552     13,201  
Taxes payable   3,296     2,671  
Other current liabilities   648     720  
Total current liabilities   21,221     21,514  
Non-current liabilities            
Long-term debt   7,229     6,646  
Provisions for contingencies   7,615     8,553  
Provisions for employee benefits   939     937  
Deferred tax liabilities   8,370     8,762  
Other non-current liabilities   1,015     417  
Total non-current liabilities   25,168     25,315  
TOTAL LIABILITIES   46,389     46,829  
SHAREHOLDERS’ EQUITY            
Minority interests   1,463     1,321  
Eni shareholders’ equity:            
Share capital: 4,005,358,876 fully paid shares nominal value euro 1 each (the same amount as of December 31, 2005)   4,005     4,005  
Other reserves   27,753     29,020  
Net profit   7,583     10,005  
Treasury shares   (4,216 )   (5,374 )
Eni shareholders’ equity   35,125     37,656  
Total shareholders’ equity   36,588     38,977  
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY   82,977     85,806  
   

 

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Property, plant and equipment determined under U.S. GAAP consist of the following:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Property, plant and equipment, gross:            
- Exploration & Production   47,891     47,852  
- Gas & Power   21,514     22,304  
- Refining & Marketing   9,059     10,939  
- Petrochemical   3,923     3,940  
- Engineering & Construction   72        
- Other activities   1,175     1,105  
- Corporate and financial companies   441     321  
- Elimination of intra-group profits   (88 )   (56 )
    83,987     86,405  
Accumulated depreciation and amortization:            
- Exploration & Production   22,790     24,265  
- Gas & Power   7,754     8,204  
- Refining & Marketing   5,503     7,111  
- Petrochemical   2,715     2,751  
- Engineering & Construction   56        
- Other activities   1,060     1,012  
- Corporate and financial companies   245     144  
- Elimination of intra-group profits   (4 )   (6 )
    40,119     43,481  
Property, plant and equipment, net:            
- Exploration & Production   25,101     23,587  
- Gas & Power   13,760     14,100  
- Refining & Marketing   3,556     3,828  
- Petrochemical   1,208     1,189  
- Engineering & Construction   16        
- Other activities   115     93  
- Corporate and financial companies   196     177  
- Elimination of intra-group profits   (84 )   (50 )
    43,868     42,924  
   

 

Property, plant and equipment by segment as at December 31, 2005 have been reclassified on the basis of the new subdivision within segments. These reclassification concern Exploration & Production, Other activities and Corporate and financial companies.
Operating profit (loss) by industry segment and profit before income taxes, as determined under U.S. GAAP, would have been as follows:

(million euro)   2004  

2005

 

2006

   
 
 
Operating profit (loss) by industry segment                  
Exploration & Production   7,963     12,690     15,784  
Gas & Power   3,371     3,237     3,681  
Refining & Marketing   811     881     605  
Petrochemical   281     202     216  
Engineering & Construction   (52 )   1        
Other activities   (406 )   (967 )   (622 )
Corporate and financial companies   (229 )   (375 )   (296 )
Elimination of intra-group profits         (141 )   (23 )
    11,739     15,528     19,345  
Net profit before income taxes   12,324     16,281     20,784  
   

 

 

Operating profit (loss) by industry segment for the periods 2004 and 2005 have been reclassified on the basis of the new subdivision within segments. These reclassification concern Exploration & Production, Other activities and Corporate and financial companies.

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38 Additional financial statement disclosures required by U.S. GAAP and the SEC

Charges related to asset retirement obligations (SFAS 143)
Changes in provisions for asset retirement obligations during the year were:

(million euro)   2004  

2005

 

2006

   
 
 
Provision for asset retirement obligations as of January 1   1,950     1,959     2,646  
New obligations incurred during the year   193     311     12  
Accretion discount   80     106     112  
Revisions of previous estimates   40     277     1,229  
Spending on existing obligations   (32 )   (107 )   (112 )
Property dispositions   (234 )            
Foreign currency translation   (36 )   110     (101 )
Other adjustments   (2 )   (10 )   (16 )
Provision for asset retirement obligations as of December 31   1,959     2,646     3,770  
   

 

 

Income taxes in accordance with U.S. GAAP
The following information is presented according to Statement of Financial Accounting Standards No. 109 "Accounting for Income Taxes". Domestic and foreign components of pre-tax income were as follows:

(million euro)   2004  

2005

 

2006

   
 
 
Domestic   5,468     4,727     6,190  
Foreign   6,856     11,554     14,594  
    12,324     16,281     20,784  
   

 

 

Income taxes were as follows:

(million euro)   2004  

2005

 

2006

   
 
 
Current   4,470     7,217     9,130  
Deferred   1,112     1,116     1,354  
    5,582     8,333     10,484  
   

 

 

The reconciliation of income taxes calculated under Italian tax regulation by applying a 33% rate (Ires - national corporate income tax) to pre-tax income and a 4.25% rate (Irap - regional income tax) to net value of production as provided for by Italian laws, to the income taxes recorded on a U.S. GAAP basis is as follows:

(million euro)   2004  

2005

 

2006

   
 
 
Income before tax in accordance with U.S. GAAP   12,324     16,281     20,784  
Italian statutory tax rate (state and local) (%)   38.3     37.9     37.6  
Expected income tax provision in accordance with U.S. GAAP at Italian statutory tax rate   4,714     6,176     7,812  
Effect of items increasing (decreasing) the Italian statutory tax rate:                  
- increase (decrease) in tax effect of foreign operations   835     1,946     2,770  
- taxes on distributable reserves   446     252     11  
- permanent differences   (143 )   131     (75 )
- revaluation of deferred tax assets   (218 )   (52 )   (20 )
- benefits deriving from the application of favorable tax laws   (8 )   (11 )   (14 )
- other   (44 )   (109 )      
    5,582     8,333     10,484  
   

 

 

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NET DEFERRED TAX LIABILITIES
The most significant temporary differences giving rise to net deferred tax liabilities were as follows:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Deferred tax liabilities:            
- accelerated depreciation   6,006     6,932  
- distributable reserves subject to taxes in case of distribution   3,212     3,223  
- asset retirement costs   376     724  
- successful efforts method accounting   690     522  
- excess cost paid for the acquisition of consolidated investments   485     431  
- capitalization of interest expense   245     232  
- provisions for uncollectible receivables   84     85  
- provisions for contingencies   50     47  
- gains taxable in the future   34     23  
- other   775     805  
    11,957     13,024  
Deferred tax assets:            
- accruals for impairment losses on receivables and contingencies   (1,949 )   (2,555 )
- revaluation of assets in accordance with Law No. 342/2000 and No. 448/2001   (1,186 )   (1,028 )
- depreciation and amortization of assets   (904 )   (749 )
- tax losses carryforwards   (510 )   (337 )
- impairment losses on assets and inventories   (135 )   (120 )
- expense on investments   (237 )   (67 )
- other   (1,062 )   (927 )
    (5,983 )   (5,783 )
Less:            
- valuation allowance   549     376  
    (5,434 )   (5,407 )
Net deferred tax liabilities   6,523     7,617  
   

 

The valuation allowance relates to deferred tax assets of euro 376 million (euro 549 million at December 31, 2005) of consolidated companies whose expected future fiscal profits are not considered sufficient for the utilization of these assets.

TAX LOSSES CARRYFORWARDS
The difference in tax losses carryforwards between IFRS and U.S. GAAP relates to the companies which are consolidated under IFRS (see Note 22 - Deferred tax liabilities), but excluded from consolidation according to U.S. GAAP.

Investments
At December 31, 2005 and 2006, investments accounted for under the equity method of euro 4,589 million and euro 4,305 million, respectively, included shares of Saipem SpA, which is listed on the Italian Stock Exchange. The following information includes its fair value:

   

Number of Eni shares

 

Equity ratio
(%)

 

Share price
(euro)

 

Market value
(million euro)

   
 
 
 
December 31, 2005                        
Saipem SpA  

189,423,307

   

43.26

   

13.79

   

2,613

 
December 31, 2006                        
Saipem SpA  

189,423,307

   

43.54

   

19.71

   

3,734

 
   
 
 
 

In 2004, 2005 and 2006, Saipem SpA was included in the consolidation under IFRS, while, under U.S. GAAP, it is valued under the equity method. Information about Saipem SpA and its subsidiaries (as indicated in Saipem consolidated financial statements),

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that include SnamProgetti SpA acquired by Saipem in 2006 (see Note 36 - Reconciliation of net profit and shareholders’ equity determined under IFRS to U.S. GAAP - A), representing a 100% share of the companies, is as follows:

(million euro)  

Dec. 31, 2005

 

Dec. 31, 2006

   
 
Total assets   5,968     9,531  
- current   3,101     6,087  
- non current   2,867     3,444  
Total liabilities   4,325     7,946  
- current   3,633     6,664  
- non current   692     1,282  
   

 

 

(million euro)   2004  

2005

 

2006

   
 
 
Net sales from operations   4,306     4,528     7,517  
Operating profit   328     365     599  
Net profit   235     255     384  
   

 

 

Concentrations and certain significant estimates
The following information is presented according to Statement of Position 94-6 "Disclosures of Certain Significant Risks and Uncertainties".

NATURE OF OPERATIONS
Eni is an integrated energy company operating in the oil and gas, electricity generation, petrochemicals and oilfield services and engineering industries.

EXPLORATION & PRODUCTION: through its Exploration & Production Division and subsidiaries, Eni engages in hydrocarbon exploration and production in Italy, North Africa (Algeria, Egypt, Libya and Tunisia), West Africa (Angola, Congo and Nigeria), the North Sea (Norway and the United Kingdom), Latin America (Venezuela), the former Soviet Union countries (mainly Kazakhstan), the United States (Gulf of Mexico and Alaska) and Asia (mainly Saudi Arabia, China, India, Indonesia, Iran and Pakistan). In 2005 approximately 68% of oil production sold was supplied to Eni’s Refining & Marketing segment and approximately 40% of natural gas production sold was supplied to Eni’s Gas & Power segment.
Eni owns a storage system, made up by eight depleted fields, which is used for the modulation of supply in accordance with seasonal swings in demand (natural gas is stored in the summer and used in the winter), as strategic reserve to ensure supply and to support domestic production through mineral storage. Storage assets are owned by Stoccaggi Gas Italia (Eni 100%), a company constituted in accordance with Law Decree No. 164/2000 that introduced laws for the liberalization of the Italian natural gas market.

GAS & POWER: Econstituted by ni is engaged in the supply, transmission and sale of natural gas in Italy and outside Italy through its Gas & Power Division, which was the incorporation of Snam SpA into Eni SpA in 2002, and through certain subsidiaries. Approximately 92% of total purchases are purchased from foreign sources (primarily Algeria, Russia, The Netherlands and Norway) under long-term contracts, which contain take-or-pay provisions, and transported to Italy through a network of over 4,300 kilometers of international pipelines of which Eni owns the transmission rights. The remaining purchases in Italy are obtained principally from domestic gas produced by Eni’s Exploration & Production segment. Through an approximately 30,800-kilometer long network (corresponding approximately to 96% of the Italian domestic natural gas network), Eni supplies natural gas to residential and commercial users (civil market), industrial users and the power generation segment. Snam Rete Gas (Eni 53.39%), that was constituted in accordance with Law Decree No. 164/2000, owns the pipelines network used by Eni. Snam Rete Gas, a company listed on the Italian Stock Exchange, engages in natural gas transportation activities also for other operators of the segment. Following the merging of Italgas Più, Eni supplies natural gas directly to approximately five million customers in the residential and commercial segment. Through Italgas (Eni 100%), Eni is engaged in domestic distribution of natural gas in Italy through an approximately 48,000-kilometer long network.
Eni is engaged in distribution and sale of natural gas to residential and commercial customers outside Italy, in Argentina through Distribuidora de Gas Cuyana, in Hungary through Tigáz and in Slovenia through Adriaplin.
Legislative Decree No.164/2000 introduced laws for the liberalization of the Italian natural gas market with great impact on Eni’s activities, as the company is present in all the phases of the natural gas chain. The most important aspects of the decree are the following:
- total free market after 2003;

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- until December 31, 2010 the imposition of thresholds to operators in relation to a percentage share of domestic consumption set as follows: (i) 75%, by January 1, 2002, for imported or domestically produced natural gas volumes introduced in the domestic transmission network in order to sell it. This percentage decreases by two percentage points per year until it reaches 61% in 2009; (ii) 50% from January 1, 2003 for sales to final customers. These ceilings are calculated net of own consumption and, in case of sales, also net of losses. In 2006 Eni’s presence in the Italian natural gas market was in accordance with the above limitations;
- tariffs for transport infrastructure, storage, use of LNG terminals and distribution networks are set by the Authority for Electricity and Gas;
- third parties are allowed to access natural gas infrastructure according to set conditions.
Eni through EniPower SpA (Eni 100%) and subsidiaries is engaged in managing Eni’s electricity business at the power plants located in the Ferrera Erbognone, Ravenna, Livorno, Taranto, Mantova, Brindisi and Ferrara industrial sites with installed capacity of 4.5 gigawatts and a production sold of 24.82 terawatthours. The demand for gas and fuel oils of EniPower’s stations is met by Eni supplies.

REFINING & MARKETING: Eni, through its Refining & Marketing Division, which was constituted by the incorporation of AgipPetroli SpA in Eni SpA in 2002 and certain subsidiaries, engages in petroleum refining and marketing activities primarily in Italy and Europe. Eni is the largest refiner of petroleum products in Italy in terms of overall refining capacity. Approximately 56% of crude oil sold is purchased from Eni’s Exploration & Production segment, the rest is purchased from producing countries pursuant to purchase contracts (28%) and in spot markets (16%). Approximately 58% of the purchased crude oil is refined. 35.9% of oil refined derives from the production of Eni’s Exploration & Production segment.

PETROCHEMICALS: through Polimeri Europa SpA and subsidiaries (Eni 100%), Eni engages in manufacturing of olefins, aromatics, intermediate products, styrene and elastomers. Eni’s petrochemicals production is concentrated in Italy, the other operations being primarily in Western Europe. Approximately 23% of the oil-based feedstock requirements used by petrochemical plants are supplied by Eni’s Refining & Marketing segment.

ENGINEERING & CONSTRUCTION: through Saipem SpA (Eni 43%), a company listed on the ItalianStock Exchange, and its subsidiaries, Eni is engaged in construction and drilling services to customers in the oil and gas industries and is a provider of engineering and project management services to customers in the oil and gas and petrochemical industries. At December 31, 2006, 20% of the order backlog related to orders from Eni Group companies.

Accounting for suspended well costs
Effective January 1, 2005 Eni adopted Position FAS 19-1 (FSP 19-1), "Accounting for Suspended Well Costs". FSP 19-1 amended Statement of Financial Accounting Standards No. 19 (FAS 19) "Financial Accounting and Reporting by Oil and Gas Producing Companies". Following adoption of FSP 19-1, Eni temporarily capitalized exploratory drilling costs pending determination of whether the well has found proved reserves if both of the following conditions are met: (a) the well has found a sufficient quantity of reserves to justify, if appropriate, its completion as a producing well; and (b) the enterprise is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if an enterprise obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well would be assumed to be impaired, and its costs, net of any salvage value, would be charged to expense. FSP 19-1 provided a number of indicators needing to be present to demonstrate sufficient progress was being made in assessing the reserves and economic viability of the project. Among these indicators are: (i) costs are being incurred to assess the reserves and their potential development; (ii) existence (or active negotiations) of sales contracts with customers for oil and natural gas; and (iii) existence of firm plans, established timetables or contractual commitments, which may include seismic testing and drilling of additional exploratory wells. The disclosures and discussion below address those suggested in FSP 19-1.

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The following table reflects the net changes in capitalized exploratory well costs during 2006 and 2005:

(million euro)  

2005

 

2006

   
 
Capitalized exploratory well costs as at January 1   513     551  
Addition pending determination of proved reserves   128     384  
Amount previously capitalized expended during the year   (96 )   (64 )
Reclassification to wells, facilities and equipment based on the determination of proved reserves   (67 )   (45 )
Property dispositions   (1 )   (3 )
Foreign exchange changes   74     (71 )
Capitalized exploratory well costs as at December 31   551     752  
   

 

The following table provides an analysis of capitalized exploratory well costs based on the date the drilling was completed:

 

    2005   2006
   
 
    million euro   No. of Eni’s Net Wells   million euro   No. of Eni’s Net Wells
   
 
 
 
< 1 year   148   9.35   360   15.54
1 to 3 years   323   24.09   272   13.71
3 to 8 years   80   5.53   120   11.27
    551   38.97   752   40.52
   
 
 
 

The following table provides capitalized exploratory well costs and the related Eni’s net well divided by category of projects:

    2005   2006
   
 
    million euro   No. of Eni’s Net Wells   million euro   No. of Eni’s Net Wells
   
 
 
 
Project with wells drilled in the past 12 months   148   9.35   360   15.54
Project with recent or planned exploratory activity   344   21.21   307   15.18
Project with exploration activities already underway or firmly planned:                
- future exploration drilling   159   9.37   186   9.79
- other exploratory activities   185   11.84   121   5.39
Project with completed exploratory activity   59   8.41   85   9.80
Project progressing towards commercialization/sanctioning   45   6.22   63   7.00
Project waiting finalization of development facilities   14   2.19   22   2.80
Total/Number of wells at the year end   551   38.97   752   40.52
   
 
 
 

At the end of 2006 of the euro 752 million of exploratory suspended costs, approximately euro 360 million related to the 15.54 Eni’s net wells for which the drilling was completed in one year or less. Of the remaining euro 392 million, related to the 24.98 Eni’s net wells suspended for more than one year since the completion of drilling, 78% was associated with projects for which exploration activity is still ongoing.

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Changes in accounting principles

On September 2005, the Emerging Issues Task Force ("EITF") issued Issue No. 04-13 ("EITF 04-13"), "Accounting for Purchases and Sales of Inventory with the Same Counterparty." The EITF concluded that inventory purchases and sales transactions with the same counterparty should be combined for accounting purposes if they were entered into in contemplation of each other. The EITF provided indicators to be considered for purposes of determining whether such transactions are entered into in contemplation of each other. Guidance was also provided on the circumstances under which non-monetary exchanges of inventory within the same line of business should be recognized at fair value. EITF 04-13 became effective in reporting periods beginning after March 15, 2006. Eni adopted EITF 04-13 starting from April 1, 2006. The adoption of EITF 04-13 did not have material effect on Eni’s Consolidated Financial Statements according to U.S. GAAP.
Effective January 1, 2006, the Company adopted SFAS No. 123-R, "Share-Based Payment" ("SFAS 123R"), using the modified prospective method. SFAS 123R establishes the accounting for equity instruments exchanged for employee services. Under SFAS 123R, share-based compensation cost is measured at the grant date based on the calculated fair value of the award. The expense is recognized over the employees’ requisite service period, generally the vesting period of the award. SFAS 123R also requires the related excess tax benefit received upon exercise of stock options or vesting of restricted stock, if any, to be reflected in the statement of cash flows as a financing activity rather than an operating activity. The adoption of this standard did not have material effect on Eni’s Consolidated Financial Statements according to U.S. GAAP.

As of December 31, 2006, Eni applies SFAS 158 which requires that the provision for employees benefits equals the total actuarial liability and therefore includes the total amount of incomes and losses resulting from changes in actuarial assumptions. Actuarial incomes and losses not accounted in the profit and loss account are recognized, net of the related fiscal effect, with a corresponding entry to the item of the shareholders’ equity "Other comprehensive income". In the following periods, the actuarial profits and losses "suspended" in other comprehensive income are recognized in the profits and loss account according to the corridor method.
The effect of the adoption of SFAS 158 consist in the following:

(million euro)  

Net actuarial losses at December 31, 2005   128  
Net actuarial losses recognized in 2006 profit and loss account   (28 )
Change in net actuarial losses   (65 )
Change in consolidation   (3 )
Net actuarial losses at December 31, 2006   32  
   

Actuarial losses expected to be recognized in profit and loss account during 2007 amount to euro 3 million.

Recent accounting principles
On June 2006, FASB issued Interpretation No. 48 "Accounting for uncertainty in income taxes" (FIN 48) that prescribes criteria for recognition and measurement of entity’s tax benefits ("tax positions") which present uncertainty regards of being realized. The requirements of FIN 48 prescribes that an entity shall recognize in financial statements defined tax positions only when it is considered "more likely than not" that their positive effects will be realized. The value of the tax position that shall be recognized in financial statements is measured at the largest amount of benefit that is greater than 50% likely of being realized.
Any differences between tax positions taken in a tax return and amounts recognized in the financial statements represent liabilities to be recognized in the balance sheet. FIN 48 is effective starting from January 1, 2007.
On September 2006, FASB issued Statement of Financial Accounting Standard n. 157 "Fair value measurement" (SFAS 157). SFAS 157 establishes a framework that applies when U.S. GAAP require fair value measurements of asset and liabilities. According to SFAS 157, fair value is measured mainly on the assumptions used by market participants rather than entity internal assumptions. The use of entity internal assumptions is allowed only for situations in which there are no information readily available on the market; therefore, in this circumstance, the entity adapts its internal assumptions to those used by market participants. SFAS 157 establishes a fair value "hierarchy" articulated on three levels according to the different quality of input used in the measurement. SFAS 157 is effective starting from 2008.
On February 2007, FASB issued Statement of Financial Accounting Standard No. 159 "The Fair Value option for Financial Assets and Financial Liabilities - Including an Amendment of FASB Statement No. 115" (SFAS 159). SFAS 159, in order to permit consistent measurement of assets and liabilities connected, reducing volatility of financial results, provides the option to evaluate certain financial and non financial asset and liabilities at fair value (fair value option). The decision of apply fair value option is irrevocable. SFAS 159 is effective starting from 2008.
Eni presently is analyzing the new accounting principles and, at the moment, cannot determine if their adoption will have a significant effect on Eni’s Consolidated Financial Statements according to U.S. GAAP.

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Supplemental oil and gas information (unaudited)
The following information is presented in accordance with Statement of Financial Accounting Standards No. 69 "Disclosures about Oil & Gas Producing Activities". Amounts related to minority interests are not significant.

CAPITALIZED COSTS
Capitalized costs represent the total expenditures for proved and unproved mineral interests and related support equipment and facilities utilized in oil and gas exploration and production activities, together with related accumulated depreciation, depletion and amortization. Capitalized costs by geographical area consist of the following:

(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (b)   Total
   
 
 
 
 
 
 
 
December 31, 2005                                                
Proved mineral interests (a)   9,756     9,321     8,733     8,350     9,463     45,623     435     46,058  
Unproved mineral interests   33     197     134     413     1,265     2,042     55     2,097  
Support equipment and facilities   253     1,385     272     33     93     2,036     9     2,045  
Incomplete wells and other   657     638     728     221     1,895     4,139     53     4,192  
Gross Capitalized Costs   10,699     11,541     9,867     9,017     12,716     53,840     552     54,392  
Accumulated depreciation, depletion and amortization   (6,888 )   (5,113 )   (5,193 )   (4,619 )   (4,697 )   (26,510 )   (316 )   (26,826 )
Net Capitalized Costs   3,811     6,428     4,674     4,398     8,019     27,330     236     27,566  
December 31, 2006                                                
Proved mineral interests (a)   10,780     9,335     8,476     8,790     9,424     46,805     436     47,241  
Unproved mineral interests   33     132     385     460     1,106     2,116     35     2,151  
Support equipment and facilities   287     1,238     451     33     98     2,107     8     2,115  
Incomplete wells and other   655     599     812     300     2,248     4,614     51     4,665  
Gross Capitalized Costs   11,755     11,304     10,124     9,583     12,876     55,642     530     56,172  
Accumulated depreciation, depletion and amortization   (7,184 )   (5,403 )   (5,402 )   (5,345 )   (5,187 )   (28,521 )   (311 )   (28,832 )
Net Capitalized Costs   4,571     5,901     4,722     4,238     7,689     27,121     219     27,340  
   

 

 

 

 

 

 

 

     
(a)   Includes capitalized costs for wells and facilities related to proved reserves.
(b)   Starting from 2005 are included data related to joint venture and affiliates accounted under the equity method.

COSTS INCURRED
Costs incurred represent amounts both capitalized and expensed in connection with oil and gas producing activities. Cost incurred by geographical area consist of the following:

(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (b)   Total
   
 
 
 
 
 
 
 
2004                                                
Exploration   64     104     71     66     194     499           499  
Development (a)   431     965     881     391     1,407     4,075           4,075  
Total costs incurred   495     1,069     952     457     1,601     4,574           4,574  
2005                                                
Proved property acquisitions   19           16           99     134           134  
Unproved property acquisitions   13           44           99     156           156  
Exploration   45     153     75     127     264     664     18     682  
Development (a)   644     960     909     528     1,396     4,437     31     4,468  
Total costs incurred   721     1,113     1,044     655     1,858     5,391     49     5,440  
2006                                                
Proved property acquisitions   139     10                       149           149  
Unproved property acquisitions                           3     3           3  
Exploration   128     270     471     174     305     1,348     26     1,374  
Development (a)   1,120     893     963     538     1,365     4,879     31     4,910  
Total costs incurred   1,387     1,173     1,434     712     1,673     6,379     57     6,436  
   

 

 

 

 

 

 

 

     
(a)   Includes for assets retirement obligations pursuant to SFAS 143 "Accounting for asset retirement obligations" euro 233 million of costs capitalized during 2004, euro 588 million for 2005 and euro 1,241 million for 2006.
(b)   Starting from 2005 are included data related to joint venture and affiliates accounted under the equity method.

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RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING ACTIVITIES
Results of operations from oil and gas producing activities, including gas storage services used to modulate the seasonal variation of demand, represent only those revenues and expenses directly associated to such activities including operating overheads. These amounts do not include any allocation of interest expense or general corporate overhead and, therefore, are not necessarily indicative of the contributions to consolidated net earnings of Eni. Related income taxes are computed by applying the local income tax rates to the pre-tax income from producing activities. Eni is a party to certain Production Sharing Agreements (PSAs) whereby a portion of Eni’s share of oil and gas production is withheld and sold by its joint venture partners which are state-owned entities, with proceeds being remitted to the state in satisfaction of Eni’s PSA-related tax liabilities. Revenue and income taxes include such taxes owed by Eni but paid by state-owned entities out of Eni’s share of oil and gas production. Results of operations from oil and gas producing activities by geographical area consist af the following:

(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (b)   Total
   
 
 
 
 
 
 
 
2004                                                
Revenues                                                
Sales to consolidated entities   2,633     1,868     2,762     2,083     508     9,854           9,854  
Sales to third parties   148     1,364     306     709     2,086     4,613           4,613  
Total revenues   2,781     3,232     3,068     2,792     2,594     14,467           14,467  
Operations costs   (223 )   (292 )   (322 )   (405 )   (289 )   (1,531 )         (1,531 )
Production taxes   (118 )   (91 )   (379 )   (13 )   (163 )   (764 )         (764 )
Exploration expenses   (57 )   (47 )   (71 )   (93 )   (155 )   (423 )         (423 )
D.D. & A. and Provision for abandonment (a)   (489 )   (437 )   (482 )   (687 )   (849 )   (2,944 )         (2,944 )
Other income and (expenses)   (98 )   (368 )   (216 )   97     (208 )   (793 )         (793 )
Accretion discount (SFAS 143)   (37 )   (5 )   (17 )   (15 )   (6 )   (80 )         (80 )
Pretax income from producing activities   1,759     1,992     1,581     1,676     924     7,932           7,932  
Income taxes   (632 )   (994 )   (945 )   (948 )   (305 )   (3,824 )         (3,824 )
Results of operations from E&P activities   1,127     998     636     728     619     4,108           4,108  
2005                                                
Revenues                                                
Sales to consolidated entities   3,133     2,813     4,252     2,707     828     13,733           13,733  
Sales to third parties   161     2,579     394     889     2,883     6,906     106     7,012  
Total revenues   3,294     5,392     4,646     3,596     3,711     20,639     106     20,745  
Operations costs   (261 )   (390 )   (363 )   (417 )   (338 )   (1,769 )   (16 )   (1,785 )
Production taxes   (157 )   (98 )   (513 )   (15 )   (207 )   (990 )   (3 )   (993 )
Exploration expenses   (32 )   (59 )   (38 )   (125 )   (181 )   (435 )   (30 )   (465 )
D.D. & A. and Provision for abandonment (a)   (512 )   (711 )   (632 )   (710 )   (1,007 )   (3,572 )   (58 )   (3,630 )
Other income and (expenses)   (205 )   (400 )   (176 )   55     (251 )   (977 )   7     (970 )
Accretion discount (SFAS 143)   (45 )   (9 )   (15 )   (31 )   (6 )   (106 )         (106 )
Pretax income from producing activities   2,082     3,725     2,909     2,353     1,721     12,790     6     12,796  
Income taxes   (762 )   (2,197 )   (1,818 )   (1,386 )   (580 )   (6,743 )   (19 )   (6,762 )
Total results of operations from E&P activities   1,320     1,528     1,091     967     1,141     6,047     (13 )   6,034  
2006                                                
Revenues                                                
Sales to consolidated entities   3,601     4,185     4,817     3,295     973     16,871           16,871  
Sales to third parties   184     3012     967     983     2,594     7,740     120     7,860  
Total revenues   3,785     7,197     5,784     4,278     3,567     24,611     120     24,731  
Operations costs   (249 )   (496 )   (475 )   (481 )   (338 )   (2,039 )   (18 )   (2,057 )
Production taxes   (181 )   (95 )   (475 )         (82 )   (833 )   (3 )   (836 )
Exploration expenses   (70 )   (101 )   (90 )   (100 )   (193 )   (554 )   (9 )   (563 )
D.D. & A. and Provision for abandonment (a)   (454 )   (869 )   (778 )   (755 )   (1,015 )   (3,871 )   (42 )   (3,913 )
Other income and (expenses)   (287 )   (569 )   (195 )   44     (343 )   (1,350 )   7     (1,343 )
Accretion discount (SFAS 143)   (34 )   (12 )   (12 )   (40 )   (14 )   (112 )         (112 )
Pretax income from producing activities   2,510     5,055     3,759     2,946     1,582     15,852     55     15,907  
Income taxes   (928 )   (2,979 )   (2,094 )   (1,821 )   (600 )   (8,422 )   (31 )   (8,453 )
Results of operations from E&P activities   1,582     2,076     1,665     1,125     982     7,430     24     7,454  
   

 

 

 

 

 

 

 

     
(a)   Includes asset impairments amounting to euro 300 million for 2004, euro 147 million for 2005 and euro 134 million for 2006.
(b)   Starting from 2005 are included data related to affiliates and joint ventures evaluated with equity method.

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OIL AND NATURAL GAS RESERVES
Proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under technical, contractual, economic and operating conditions existing at the time. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions.
Net proved reserves exclude royalties and interests owned by others.
Proved developed oil and gas reserves are proved reserves that can be estimated to be recovered through existing wells with existing equipment and operating methods.
Proved undeveloped oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for completion.
Additional oil and gas reserves expected to be obtained through the application of fluid injection or other improved recovery techniques for supplementing natural forces and mechanisms of primary recovery are included as proved developed reserves only after testing by a pilot project or after the operation of an installed program has confirmed, through production response, that increased recovery will be achieved.
Eni’s proved reserves have been estimated on the basis of the applicable U.S. Securities & Exchange Commission regulation, Rule 4-10 of Regulation S-X and its interpretations and have been disclosed in accordance with Statement of Financial Accounting Standard No. 69. The estimates of proved reserves, developed and undeveloped for years ended December 31, 2003, 2004, 2005 and 2006 are based on data prepared by Eni. Since 1991, Eni has requested qualified independent oil engineering companies carry out an independent evaluation12 of its proved reserves on a rotational basis. In particular a total of 1.4 billion boe of proved reserves, or about 21% of Eni’s total proved reserves at December 31, 2006, have been evaluated. The results of this independent evaluation confirmed Eni’s evaluations, as in previous years. In the 2004-2006 three-year period, 76% of Eni’s total proved reserves were subject to independent evaluations.
Eni operates under Production Sharing Agreements, (PSAs), in several of the foreign jurisdictions where it has oil and gas exploration and production activities. Reserves of oil and natural gas to which Eni is entitled under PSA arrangements are shown in accordance with Eni’s economic interest in the volumes of oil and natural gas estimated to be recoverable in future years. Such reserves include estimated quantities allocated to Eni for recovery of costs, income taxes owed by Eni but settled by its joint venture partners (which are state-owned entities) out of Eni’s share of production and Eni’s net equity share after cost recovery.
Proved oil and gas reserves associated with PSAs represented 51%, 48% and 53% of total proved reserves as of year-end 2004, 2005 and 2006, respectively, on an oil-equivalent basis.
A similar scheme to PSAs applies to Service and "Buy-Back" contracts; proved reserves associated with such contracts represented 3%, 2% and 2% of total proved reserves on an oil-equivalent basis as of year-end 2004, 2005 and 2006, respectively.
Oil and gas reserve quantities include: (i) oil and natural gas quantities in excess to cost recovery which the company has an obligation to purchase under certain PSAs with governments or authorities whereby the company serves as producer of reserves. In accordance with SFAS No. 69, paragraph 13, reserve volumes associated with such oil and gas quantities represented 1.4%, 1.7% and 1.1% of total proved reserves as of year-end 2004, 2005 and 2006 respectively, on an oil-equivalent basis; (ii) volumes of natural gas used for own consumption and (iii) volumes of natural gas held in certain Eni storage fields in Italy. Proved reserves attributable to these fields include: (a) the residual natural gas volumes of the reservoirs and (b) natural gas volumes from other Eni fields input into these reservoirs in subsequent periods. Proved reserves do not include volumes owned by or acquired from third parties. Gas withdrawn from storage is produced and thereby detracted from proved reserves when sold.
Numerous uncertainties are inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures. The accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Results of drilling, testing and production after the date of the estimate may require substantial upward or downward revision. In addition, changes in oil and natural gas prices have an effect on the quantities of Eni’s proved reserves since estimates of reserves are based on prices and costs relative to the date when such estimates are made. Reserve estimates are also subject to revision as prices fluctuate due to the cost recovery feature under certain PSAs.
The following table presents yearly changes by geographical area in estimated proved reserves, developed and undeveloped, of crude oil (including condensate and natural gas liquids) and natural gas for the years 2004, 2005 and 2006.


     
(12)   From 1991 to 2002 to DeGolyer and MacNaughton, from 2003 also to Ryder Scott Company.

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CRUDE OIL (INCLUDING CONDENSATES AND NATURAL GAS LIQUIDS)

(million barrels)

Proved Oil Reserves  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (a)   Total
   
 
 
 
 
 
 
 
Reserves at December 31, 2003   252     1,080     1,038     529     1,239     4,138           4,138  
Revisions of Previous Estimates   (1 )   (22 )   44     12     (18 )   15           15  
Improved Recovery         11     48     4           63           63  
Extensions and Discoveries   4     20     34     4     144     206           206  
Production   (30 )   (94 )   (104 )   (74 )   (75 )   (377 )         (377 )
Sales of Minerals in Place         (2 )   (4 )   (25 )   (6 )   (37 )         (37 )
Reclassification 2004 joint ventures and affiliates         (26 )   (9 )         (1 )   (36 )   36        
Reserves at December 31, 2004   225     967     1,047     450     1,283     3,972     36     4,008  
Purchase of Minerals in Place   2           6           47     55           55  
Revisions of Previous Estimates   33     36     (47 )   27     (88 )   (39 )   (9 )   (48 )
Improved Recovery         43     29           15     87           87  
Extensions and Discoveries         26     14     21     16     77           77  
Production   (32 )   (111 )   (113 )   (65 )   (83 )   (404 )   (2 )   (406 )
Sales of Minerals in Place                                                
Reserves at December 31, 2005   228     961     936     433     1,190     3,748     25     3,773  
Revisions of Previous Estimates (b)   15     61     (85 )   20     53     64     1     65  
Improved Recovery         49     41           14     104     1     105  
Extensions and Discoveries         30     11           62     103           103  
Production   (28 )   (119 )   (117 )   (65 )   (61 )   (390 )   (3 )   (393 )
Sales of Minerals in Place (c)                     (2 )   (170 )   (172 )         (172 )
Reserves at December 31, 2006   215     982     786     386     1,088     3,457     24     3,481  
   

 

 

 

 

 

 

 

(million barrels)

Proved Developed Oil Reserves  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates   Total
   
 
 
 
 
 
 
 
Reserves at December 31, 2003   173     640     560     464     610     2,447           2,447  
Reserves at December 31, 2004   174     655     588     386     668     2,471           2,471  
Reserves at December 31, 2005   149     697     568     353     564     2,331     19     2,350  
Reserves at December 31, 2006   136     713     546     329     402     2,126     18     2,144  
   

 

 

 

 

 

 

 

     
(a)   Starting from 2005 are included data related to joint venture and affiliates accounted under the equity method.
(b)   Includes the effect of Eni share redetermination in the Val d’Agri concession in Italy.
(c)   Includes 170 million barrels related to unilateral termination of OSA by PDVSA for Dación field.

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NATURAL GAS

(billion cubic feet)

Proved Natural Gas Reserves  

Italy (a)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (b)   Total
   
 
 
 
 
 
 
 
Reserves at December 31, 2003   4,166     5,467     1,656     2,223     4,496     18,008           18,008  
Revisions of Previous Estimates   105     814     129     75     84     1,207           1,207  
Improved Recovery               10                 10           10  
Extensions and Discoveries   29     420           38     222     709           709  
Production   (409 )   (247 )   (66 )   (220 )   (303 )   (1,245 )         (1,245 )
Sales of Minerals in Place   (73 )   (1 )         (65 )   (115 )   (254 )         (254 )
Reclassification 2004 joint ventures and afffiliates         (21 )   (2 )         (134 )   (157 )   157        
Reserves at December 31, 2004   3,818     6,432     1,727     2,051     4,250     18,278     157     18,435  
Purchase of Minerals in Place   63           8           222     293           293  
Revisions of Previous Estimates   159     (6 )   (9 )   (18 )   (368 )   (242 )   (47 )   (289 )
Improved Recovery         11                       11           11  
Extensions and Discoveries   1     37     309     50     56     453     (20 )   433  
Production   (365 )   (357 )   (70 )   (219 )   (281 )   (1,292 )         (1,292 )
Sales of Minerals in Place                                                
Reserves at December 31, 2005   3,676     6,117     1,965     1,864     3,879     17,501     90     17,591  
Purchase of Minerals in Place                     4           4           4  
Revisions of Previous Estimates   36     154     31     53     230     504     (7 )   497  
Extensions and Discoveries   19     146     34     1     132     332           332  
Production   (340 )   (471 )   (103 )   (218 )   (305 )   (1,437 )   (15 )   (1,452 )
Sales of Minerals in Place                     (7 )         (7 )         (7 )
Reserves at December 31, 2006   3,391     5,946     1,927     1,697     3,936     16,897     68     16,965  
   

 

 

 

 

 

 

 

(billion cubic feet)

Proved Developed Natural Gas Reserves  

Italy (a)

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates   Total
   
 
 
 
 
 
 
 
Reserves at December 31, 2003   2,966     962     866     2,075     3,355     10,224           10,224  
Reserves at December 31, 2004   2,850     1,760     924     1,845     3,122     10,501           10,501  
Reserves at December 31, 2005   2,704     3,060     1,289     1,484     2,622     11,159     70     11,229  
Reserves at December 31, 2006   2,449     3,042     1,447     1,395     2,616     10,949     48     10,997  
   

 

 

 

 

 

 

 

     
(a)   Including approximately 747, 737, 760 and 754 billions of cubic feet of natural gas held in storage at December 31, 2003, 2004, 2005 and 2006 respectively.
(b)   Starting from 2005 are included data related to joint venture and affiliates accounted under the equity method.

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STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
Estimated future cash inflows represent the revenues that would be received from production and are determined by applying year-end prices of oil and gas to the estimated future production of proved reserves. Future price changes are considered only to extent provided by contractual arrangements. Estimated future development and production costs are determined by estimating the expenditures to be incurred in developing and producing the proved reserves at the end of the year. Neither the effects of price and cost escalations nor expected future changes in technology and operating practices have been considered.
The standardized measure is calculated as the excess of future cash inflows from proved reserves less future costs of producing and developing the reserves, future income taxes and a yearly 10% discount factor.
Future cash flows as of December 31, 2004, 2005 and 2006 include amounts that Eni’s Gas & Power segment and other gas companies correspond for storages services, required to support market demand flexibility needs.
Future production costs include the estimated expenditures related to the production of proved reserves plus any production taxes without consideration of future inflation. Future development costs include the estimated costs of drilling development wells and installation of production facilities, plus the net costs associated with dismantlement and abandonment of wells and facilities, under the assumption that year-end costs continue without considering future inflation. Future income taxes were calculated in accordance with the tax laws of the countries in which Eni operates.
The standardized measure of discounted future net cash flows, related to the preceding proved oil and gas reserves, is calculated in accordance with the requirements of Statement of Financial Accounting Standard No. 69. The standardized measure does not purport to reflect realizable values or fair market value of Eni’s proved reserves. An estimate of fair value would also take into account, among other things, the expected recovery of reserves in excess of proved reserves, anticipated changes in future prices and costs and a discount factor representative of the risks inherent in producing oil and gas.

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Standardized measure of discounted future net cash flows by geographical area consist of the following:

(million euro)  

Italy

 

North Africa

 

West Africa

 

North Sea

 

Rest of World

 

Total consolidated

  Total joint venture and affiliates (a)   Total
   
 
 
 
 
 
 
 
At December 31, 2004                                                
Future cash inflows   28,582     40,373     28,395     20,435     32,619     150,404           150,404  
Future production costs   (3,635 )   (7,237 )   (6,664 )   (5,082 )   (4,858 )   (27,476 )         (27,476 )
Future development and abandonment costs   (2,210 )   (4,073 )   (1,873 )   (1,419 )   (2,873 )   (12,448 )         (12,448 )
Future net inflow before income tax   22,737     29,063     19,858     13,934     24,888     110,480           110,480  
Future income tax   (7,599 )   (11,487 )   (10,949 )   (8,824 )   (6,736 )   (45,595 )         (45,595 )
Future net cash flows   15,138     17,576     8,909     5,110     18,152     64,885           64,885  
10 % discount factor   (6,006 )   (7,592 )   (3,267 )   (1,350 )   (9,412 )   (27,627 )         (27,627 )
Standardized measure of discounted future net cash flows   9,132     9,984     5,642     3,760     8,740     37,258           37,258  
At December 31, 2005                                                
Future cash inflows   36,203     66,100     45,952     30,835     50,590     229,680     1,055     230,735  
Future production costs   (4,609 )   (10,030 )   (9,604 )   (5,632 )   (6,399 )   (36,274 )   (226 )   (36,500 )
Future development and abandonment costs   (2,936 )   (3,960 )   (2,594 )   (1,774 )   (4,059 )   (15,323 )   (89 )   (15,412 )
Future net inflow before income tax   28,658     52,110     33,754     23,429     40,132     178,083     740     178,823  
Future income tax   (9,890 )   (22,744 )   (21,056 )   (15,225 )   (12,097 )   (81,012 )   (187 )   (81,199 )
Future net cash flows   18,768     29,366     12,698     8,204     28,035     97,071     553     97,624  
10 % discount factor   (7,643 )   (12,095 )   (4,122 )   (2,155 )   (15,705 )   (41,720 )   (182 )   (41,902 )
Standardized measure of discounted future net cash flows   11,125     17,271     8,576     6,049     12,330     55,351     371     55,722  
At December 31, 2006                                                
Future cash inflows   43,495     64,381     34,935     24,821     48,591     216,223     1,038     217,261  
Future production costs   (6,086 )   (9,707 )   (8,028 )   (6,426 )   (5,915 )   (36,162 )   (224 )   (36,386 )
Future development and abandonment costs   (6,739 )   (5,383 )   (2,865 )   (2,265 )   (4,576     (21,828 )   (79 )   (21,907 )
Future net inflow before income tax   30,670     49,291     24,042     16,130     38,100     158,233     735     158,968  
Future income tax   (10,838 )   (24,639 )   (14,141 )   (10,901 )   (11,473 )   (71,992 )   (227 )   (72,219 )
Future net cash flows   19,832     24,652     9,901     5,229     26,627     86,241     508     86,749  
10 % discount factor   (11,493 )   (10,631 )   (2,994 )   (1,392 )   (16,504 )   (43,014 )   (154 )   (43,168 )
Standardized measure of discounted future net cash flows   8,339     14,021     6,907     3,837     10,123     43,227     354     43,581  
   

 

 

 

 

 

 

 

     
(a)   Starting from 2005 are included data related to affiliates and joint ventures evaluated with equity method.

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CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
Changes in standardized measure of discounted future net cash flows for the years 2004, 2005 and 2006.

(million euro)  

2004

 

2005

 

2006

   
 
 
Beginning of year   31,264     37,258     55,722  
Beginning of year joint venture and affiliates data         (357 )   (371 )
Beginning of year consolidated   31,264     36,901     55,351  
Increase (Decrease):                  
- sales, net of production costs   (12,172 )   (17,880 )   (21,739 )
- net changes in sales and transfer prices, net of production costs   13,031     33,372     4,097  
- extensions, discoveries and improved recovery, net of future production and development costs   2,806     3,527     3,629  
- abandonment costs   (3,437 )   (3,654 )   (6,964 )
- future development costs   4,229     3,865     3,558  
- revisions of quantity estimates   1,658     47     383  
- accretion of discount   5,328     6,573     9,489  
- net change in income taxes   (4,805 )   (17,327 )   3,060  
- purchase of reserves in-place         977     10  
- sale of reserves in-place   (727 )         (1,252 )
- changes in production rates (timing) and other   83     8,950     (6,395 )
Net increase (decrease)   5,994     18,450     (12,124 )
Standardized measure of discounted future net cash flows consolidated   37,258     55,351     43,227  
Standardized measure of discounted future net cash flows joint ventures and affiliates (a)         371     354  
Standardized measure of discounted future cash flows   37,258     55,722     43,581  
   

 

 

     
(a)   Starting from 2005 are included data related to affiliates and joint ventures evaluated with equity method.

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  Società per Azioni
Headquarters: Rome, Piazzale Enrico Mattei, 1
Capital Stock:
euro 4,005,358,876 fully paid
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