UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 20-F

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

for the fiscal year ended December 31, 2007
Commission File Number 1-32297

CPFL ENERGIA S.A.

(Exact name of registrant as specified in its charter)

CPFL ENERGY INCORPORATED	The Federative Republic of Brazil
(Translation of registrant’s name into English)	(Jurisdiction of incorporation or organization)

________________________________________________

Rua Gomes de Carvalho, 1,510, 14° andar - Cj 1402
CEP 04547-005 Vila Olímpia - São Paulo, São Paulo
Federative Republic of Brazil
+55 11 3841-8513
(Address of principal executive offices)

________________________________________________

José Antonio de Almeida Filippo
+55 19 3756 8704 - jfilippo@cpfl.com.br
Rodovia Campinas Mogi Mirim, km 2,5 – Campinas, São Paulo - 13088 900
Federative Republic of Brazil
 (Name, telephone, e-mail and/or facsimile
number and address of company contact person)

________________________________________________

________________________________________________
Securities registered or to be registered pursuant to Section 12(b) of the Act:

Title of each class:		Name of each exchange on which registered:
Common Shares, without par value*
American Depositary Shares (as evidenced by American		New York Stock Exchange
Depositary Receipts), each representing 3 Common Shares

*Not for trading, but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

     Securities registered or to be registered pursuant to Section 12(g) of the Act: None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None

As of December 31, 2007, there were 479,910,938 common shares, without par value, outstanding

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes

No

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934.

Yes

No

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes

No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act, (Check one):

Large Accelerated Filer

Accelerated Filer

Non-accelerated Filer

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing: 

U.S. GAAP

IFRS

Other

If "Other" has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17

Item 18

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes

No

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TABLE OF CONTENTS

FORWARD-LOOKING STATEMENTS		4
CERTAIN TERMS AND CONVENTIONS		4
PRESENTATION OF FINANCIAL INFORMATION		5
PART I
ITEM 1. Identity of Directors, Senior Management and Advisers		5
ITEM 2. Offer Statistics and Expected Timetable		5
ITEM 3. Key Information		6
Selected Financial and Operating Data		6
Exchange Rates		10
Risk Factors		11
ITEM 4. Information on the Company		19
Overview		19
Our Strategy		21
Distribution		22
Purchases of Electricity		25
Customers, Analysis of Demand and Tariffs		26
Generation of Electricity		28
Electricity Commercialization and Services		33
Competition		34
Our Concessions		34
Properties		35
Environmental		35
The Brazilian Power Industry		36
ITEM 4A. Unresolved Staff Comments		47
ITEM 5. Operating and Financial Review and Prospects		47
Overview		47
Background		48
Results of Operations—2007 compared to 2006		53
Results of Operations—2006 compared to 2005		56
Capital Expenditures		58
Liquidity and Capital Resources		59
Financial and Operating Covenants		62
Off-Balance Sheet Arrangements		63
U.S. GAAP Reconciliation		63
ITEM 6. Directors, Senior Management and Employees		66
Directors and Senior Management		66
Fiscal Council		71

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Advisory Committees		71
Compensation		72
Indemnification of Officers and Directors		73
Employees		73
ITEM 7. Major Shareholders and Related Party Transactions		73
Major Shareholders		73
ITEM 8. Financial Information		77
Consolidated Statements and Other Financial Information		77
Legal Proceedings		77
ITEM 9. The Offer and Listing		78
Trading Markets		78
Price Information		78
ITEM 10. Additional Information		79
Memorandum and Articles of Incorporation		79
Allocation of Net Income and Distribution of Dividends		80
Shareholder Meetings		82
Preemptive Rights		85
Withdrawal Rights		85
Material Contracts		86
Exchange Controls and Other Limitations Affecting Security Holders		86
Taxation		86
Brazilian Tax Considerations		87
Other Relevant Brazilian Taxes		89
Certain United States Federal Income Tax Consequences		90
Backup Withholding and Information Reporting		91
Documents on Display		92
ITEM 11. Quantitative and Qualitative Disclosures about Market Risk		92
ITEM 12. Description of Securities Other than Equity Securities		93
PART II
ITEM 13. Defaults, Dividend Arrearages and Delinquencies		93
ITEM 14. Material Modifications to the Rights of Security Holders and Use of Proceeds		93
ITEM 15. Controls and Procedures		93
Internal Control over Financial Reporting		93
ITEM 16A. Audit Committee Financial Expert		95
ITEM 16B. Code of Ethics		95
ITEM 16C. Principal Accountant Fees and Services		95
ITEM 16D. Exemptions from the Listing Standards for Audit Committees		96

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ITEM 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers		96
PART III
ITEM 17. Financial Statements		96
ITEM 18. Financial Statements		96
ITEM 19. Exhibits		96
Glossary of Terms		97
Signatures		99
Ex-1.1: AMENDED AND RESTATED BYLAWS
EX-8.1: LIST OF SUBSIDIARIES
EX-10.1: AMENDED AND RESTATED SHAREHOLDERS AGREEMENT
EX-12.1: CERTIFICATION
EX-12.2: CERTIFICATION
EX-13.1: CERTIFICATION
EX-13.2: CERTIFICATION

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FORWARD-LOOKING STATEMENTS

This annual report contains information that constitutes forward-looking statements within the meaning of the U.S. Private Securities litigation Reform Act of 1995. Many of the forward-looking statements contained in this annual report can be identified by the use of forward-looking words, such as “believe,” “may,” “aim,” “estimate,” “continue,” “anticipate,” “will”, “intend,” “expect” and “potential,” among others. Forward-looking statements include information concerning our possible or assumed future results of operations, business strategies, financing plans, competitive position, industry environment, potential growth opportunities, the effects of future regulation and the effects of competition. Those statements appear in a number of places in this annual report, principally under the captions “Item 3. Key Information—Risk Factors,” “Item 4. Information on the Company” and “Item 5. Operating and Financial Review and Prospects.” We have based these forward-looking statements largely on our current beliefs, expectations and projections about future events and financial trends affecting our business. Many important factors, in addition to those discussed elsewhere in this annual report, could cause our actual results to differ substantially from those anticipated in our forward-looking statements. These factors include, among other things:

• general economic, political, demographic and business conditions in Brazil and particularly in the markets we serve;

• electricity shortages;

• changes in tariffs;

• our failure to generate electricity due to water shortages, transmission outages, operational or technical problems or physical damages to our facilities;

• potential disruption or interruption of our services;

• inflation and exchange rate variation;

• the early termination of our concessions to operate our facilities;

• increased competition in the power industry markets in which we operate;

• our inability to implement our capital expenditure plan, including our inability to arrange financing when required and on reasonable terms;

• changes in customer demand;

• existing and future governmental regulations relating to the power industry; and

• the risk factors discussed under “Item 3. Key Information—Risk Factors,” beginning on page 11.

Forward-looking statements speak only as of the date they were made, and we undertake no obligation to update or to revise them after we distribute this annual report because of new information, future events or other factors. In light of these limitations, you should not place undue reliance on forward-looking statements contained in this annual report.

CERTAIN TERMS AND CONVENTIONS

A glossary of electricity industry terms is included in this annual report, beginning on page 97.

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PRESENTATION OF FINANCIAL INFORMATION

The audited consolidated financial statements as of December 31, 2007 and 2006 and for each of the three years in the period ended December 31, 2007, included in this annual report have been prepared in accordance with Brazilian Accounting Principles, which differ in certain respects from U.S. GAAP. Note 35 to our audited consolidated financial statements provides a description of the principal differences between Brazilian Accounting Principles and U.S. GAAP, as they relate to us, and a reconciliation to U.S. GAAP of net income and shareholders’ equity.

We have translated some of the real amounts contained in this annual report into U.S. dollars. The rate used to translate such amounts was R$1.771 to US$1.00, which was the rate for the selling of U.S. dollars in effect as of December 31, 2007 as reported by the Central Bank of Brazil, or Central Bank. The U.S. dollar equivalent information presented in this annual report is provided solely for convenience of investors and should not be construed as implying that the real amounts represent, or could have been or could be converted into, U.S. dollars at such rates or at any other rate. See “Item 3. Key Information—Exchange Rates” for more information regarding exchange rates between reais and U.S. dollars.

Proportionate Consolidation of Certain Subsidiaries

Through June 2006, under Brazilian Accounting Principles, we accounted for RGE using proportionate consolidation, which means that, after eliminating intercompany transactions, we included in our financial statements 67.07% of each item in RGE’s financial statements. Under U.S. GAAP, we would have been required to account for RGE on the equity method, which means that, after eliminating intercompany transactions, we would generally have presented 67.07% of its net income on a single line of our statement of operations and 67.07% of its shareholders’ equity on a single line of our balance sheet. The difference in presentation would not have affected our net income or shareholders’ equity. See Note 35 to our audited consolidated financial statements. We would, however, have presented lower revenues, operating income and cash flows if we had accounted for RGE on the equity method under Brazilian Accounting Principles (see Note 35(iii)(s) to our audited consolidated financial statements).

We currently account for four other subsidiaries using proportionate consolidation in our financial statements prepared in accordance with Brazilian Accounting Principles and using the equity method of accounting under U.S. GAAP. Our ownership interests in these subsidiaries include 65.00% of Companhia Energética Rio das Antas, or CERAN, 51.00% of Foz do Chapecó Energia S.A., or Foz do Chapecó, 48.72% of Campos Novos Energia S.A., or ENERCAN and 25.01% of BAESA – Energética Barra Grande S.A., or BAESA. All of these subsidiaries have begun operations except for our Foz do Chapecó plant, which we expect will begin operations in 2010. See Note 2 to our audited consolidated financial statements.

ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS

Not applicable.

ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE

Not applicable.

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ITEM 3. KEY INFORMATION

Selected Financial and Operating Data

The following table presents our selected historical financial and operating data. You should read the following information in conjunction with our audited consolidated financial statements and related notes, and the information under “Item 5. Operating and Financial Review and Prospects” and “Item 8. Financial Information,” included elsewhere in this annual report.

The financial data at December 31, 2007 and 2006 and for the years ended December 31, 2007, 2006 and 2005 are derived from our audited consolidated financial statements included elsewhere in this annual report. The financial information included in this annual report has been presented in accordance with Brazilian Accounting Principles, which differ in certain respects from U.S. GAAP. Note 35 to our audited consolidated financial statements provides a description of the principal differences between Brazilian Accounting Principles and U.S. GAAP, as they relate to us, and a reconciliation to U.S. GAAP of net income and shareholders’ equity.

Solely for the convenience of the reader, real amounts as of and for the year ended December 31, 2007 have been translated into U.S. dollars at the rate as reported by the Central Bank on December 31, 2007 of R$1.771 to US$ 1.00. The U.S. dollar equivalent information should not be construed to imply that the real amounts represent, or could have been or could be converted into, U.S. dollars at such rates or at any other rate.

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STATEMENT OF OPERATIONS DATA

			For the year ended December 31,
	2007		2007		2006		2005		2004		2003
	(in millions, except per share and per ADS data)
Brazilian Accounting Principles
Operating revenues	US$ 8,021		R$ 14,207		R$ 12,227		R$ 10,907		R$ 9,549		R$ 8,082
Net operating revenues(1)	5,312		9,410		7,912		6,992		6,736		6,057
Operating costs:
Electricity purchased for resale	2,288		4,052		3,419		3,175		3,126		3,020
Electricity network usage charges	397		703		774		757		679		446
Personnel	148		263		243		200		190		169
Post-retirement benefit obligation	(27)		(47)		(7)		90		148		84
Materials	28		50		39		34		32		22
Outside services	76		134		111		98		88		84
Depreciation and amortization	193		342		297		273		251		256
Fuel usage account — CCC(1)	-		-		-		-		251		261
Energy Development Account – CDE(1)	-		-		-		-		185		78
Services rendered to third parties	3		6		21		12		9		5
Other	20		36		13		12		9		10
	3,126		5,539		4,910		4,651		4,966		4,436
Operating expenses:
Sales and marketing(1)	242		428		244		197		195		148
General and administrative	200		354		315		267		268		279
Amortization of goodwill	100		176		152		126		110		532
Other(1)	19		35		19		108		56		41
	561		993		730		698		630		1,000
Operating income	1,625		2,878		2,272		1,643		1,140		621
Financial expense, net	(209)		(371)		(151)		(212)		(568)		(821)
Nonoperating income (expense), net	(17)		(31)		50		(1)		(4)		44
Income and social contribution taxes	(468)		(828)		(734)		(336)		(244)		(104)
Net income (loss) before extraordinary item and
minority interest	931		1,648		1,437		1,094		324		(260)
Extraordinary item, net of taxes(2)	-		-		(33)		(33)		(34)		(34)
Minority interest	(3)		(5)		-		(40)		(22)		(2)
Net income (loss)	US$ 928		R$ 1,643		R$ 1,404		R$ 1,021		R$ 269		(295)
Net income (loss) per share, before extraordinary
item and minority interest (3)	1.94		3.44		3.00		2.28		0.72		(0.06)
Net income (loss) per share (3)	1.93		3.42		2.93		2.13		0.59		(0.07)
Net income (loss) per ADS, before extraordinary
item and minority interest (3)	5.82		10.31		8.99		6.84		2.15		(0.19)
Net income (loss) per ADS (3)	5.80		10.27		8.78		6.39		1.78		(0.22)
Dividends declared	881		1.561		1.334		899		265
Number of common shares outstanding at year-end (3)	480		480		480		480		452		4,119
Dividends declared per share (4)	1.84		3.25		2.78		1.87		0.59
Dividends declared per ADS (4)	5.51		9.76		8.34		5.62		1.77
U.S. GAAP
Operating revenues	7,832		13,873		11,395		9,406		8,310		7,115
Net operating revenues(1)	5,183		9,181		7,316		6,053		5,880		5,364
Operating income	1,477		2,617		1,842		1,428		1,005		873
Net income (loss)	946		1,675		1,252		1,110		359		181
Net income (loss) per share – basic (5)	1.97		3.49		2.61		2.42		0.85		0.51
Net income (loss) per ADS – basic (5)	5.91		10.48		7.83		7.26		2.55		1.54
Net income (loss) per share – diluted (5)	1.97		3.49		2.61		2.39		0.84		0.51
Net income (loss) per ADS – diluted (5)	5.91		10.48		7.83		7.18		2.51		1.54
Weighted average number of shares outstanding (5)	480		480		480		458		421		353

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BALANCE SHEET DATA

					As of December 31,
	2007		2007		2006		2005		2004		2003
					(in millions)
Brazilian Accounting Principles
Current assets:
Cash and cash equivalents	US$ 524		R$ 928		R$ 540		R$ 679		R$ 500		R$ 375
Accounts receivable	1,026		1,818		2,125		1,803		1,572		1,479
Total current assets	2,301		4,076		3,696		3,770		3,223		2,376
Non-current assets:
Accounts receivable	121		215		165		416		582		728
Total non-current assets(6)	1,443		2,555		2,046		2,745		2,709		2,417
Permanent assets:
Property, plant and equipment	4,031		7,140		6,237		5,289		4,879		4,452
Goodwill	1,449		2,566		2,807		2,619		2,347		3,237
Total permanent assets	5,061		8,964		8,307		7,336		6,725		7,278
Total assets	8,805		15,596		14,049		13,851		12,657		12,071
Current liabilities:
Short-term debt (7)	658		1,166		964		1,651		1,303		1,203
Total current liabilities	2,381		4,218		3,785		4,139		3,048		2,567
Long-term liabilities:
Long-term debt(7)	2,969		5,258		4,279		3,394		3,830		4,368
Total long-term liabilities(6)	3,577		6,335		5,395		4,916		5,451		5,979
Minority interest	50		88		2		-		137		192
Shareholder’s equity	2,797		4,955		4,866		4,796		4,021		3,333
Total liabilities and shareholders’ equity	8,805		15,596		14,049		13,851		12,657		12,071
U.S. GAAP
Shareholders’ equity	3,891		6,892		6,781		6,271		5,178		4,123
Total assets	US$ 8,769		R$ 15,532		R$ 14,435		R$ 13,938		R$ 12,952		R$ 12,658

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OPERATING DATA

		For the year ended December 31,
		2007		2006		2005		2004		2003
Energy sold (in GWh):
Residential		10,766		9,489		8,783		8,302		8,124
Industrial		16,692		16,882		16,995		17,897		16,909
Commercial		6,509		5,779		5,329		4,936		4,752
Rural		2,511		1,966		1,730		1,619		1,550
Public administration		972		862		800		746		736
Public lighting		1,284		1,152		1,098		1,070		1,048
Public services		1,590		1,472		1,400		1,358		1,352
Own consumption		30		25		25		26		27
Total energy sold to final consumers		40,354		37,627		36,160		35,954		34,498
Total customers (in thousands)(8)		6,257		5,749		5,610		5,467		5,341
Installed capacity (in MW)		1,588		1,072		915		854		812
Assured energy (in GWh)		6,698		4,962		4,214		3,807		3,804
Energy generated (in GWh)		6,382		3,407		3,126		2,734		2,633

	For the year ended
	December 31,
	2003
Net loss per share, before extraordinary item and minority interest	R$(0.63)
Net loss per share	(0.72)
Net loss per ADS, before extraordinary item and minority interest	(1.89)
Net loss per ADS	(2.15)
Number of common shares outstanding at year-end (in millions)	412

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Exchange Rates

The Central Bank allows the real/U.S. dollar exchange rate to float freely, and it has intervened occasionally to control unstable movements in foreign exchange rates. We cannot predict whether the Central Bank or the Brazilian government will continue to let the real float freely or will intervene in the exchange rate market through a currency band system or otherwise. The real may depreciate or appreciate against the U.S. dollar substantially in the future. For more information on these risks, see “Item 3. Additional Information—Risk Factors—Risks Relating to Brazil.”

The following table provides information on the selling exchange rate, expressed in reais per U.S. dollar (R$/US$), for the periods indicated. Prior to March 14, 2005, under Brazilian regulations, foreign exchange transactions were carried out on either the commercial rate exchange market or the floating rate exchange market. Rates in the two markets were generally the same. The table uses the commercial selling rate for periods prior to March 14, 2005.

				Average for
		Period-end		Period(1)		Low		High
				(reais per U.S. Dollar)
Year ended:
December 31, 2003		2.889		3.060		2.822		3.662
December 31, 2004		2.654		2.917		2.654		3.205
December 31, 2005		2.341		2.412		2.163		2.762
December 31, 2006		2.138		2.168		2.059		2.371
December 31, 2007		1.771		1.930		1.733		2.156
Month:
October 2007		1.744		1.801		1.744		1.828
November 2007		1.784		1.770		1.733		1.850
December 2007		1.771		1.786		1.762		1.823
January 2008		1.760		1.774		1.741		1.830
February 2008		1.683		1.728		1.672		1.768
March 2008		1.749		1.708		1.670		1.749
April 2008 (through April 23)		1.658		1.691		1.658		1.753

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RISK FACTORS

Risks Relating to Our Operations and the Brazilian Power Industry

We are subject to extensive governmental legislation and regulation and to major regulatory changes that are still being implemented by the Brazilian government, and we cannot be certain of their effect on our business and results of operations.

Beginning in 2004, the Brazilian government has implemented policies that have had a far-reaching impact on the Brazilian power industry and, in particular, the electricity industry. Law No. 10,848 for the New Electric Energy Industry Model (Lei do Novo Modelo do Setor Elétrico, or New Industry Model Law), which governs the operations of companies in the power industry, was enacted on March 16, 2004. The New Industry Model Law was implemented by Decree No. 5,163, dated July 30, 2004, as amended, and remains subject to further implementation by resolutions of ANEEL. Political parties are currently challenging the constitutionality of the New Industry Model Law before the Brazilian Supreme Court. The Brazilian Supreme Court has not reached a final decision yet and, therefore, the New Industry Model Law is currently in force. If all or part of the New Industry Model Law is determined to be unconstitutional by the Brazilian Supreme Court, the regulatory scheme introduced by the New Industry Model Law may not come into effect, which would create uncertainty as to how and when the Brazilian government will be able to introduce changes to the electricity sector. The outcome of the legal proceedings and future reforms in the power industry are difficult to predict, but they could have an adverse impact on the entire energy sector, including our business and results of operations. See “Item 4. Information on the Company—The Brazilian Power Industry.”

We are uncertain as to the renewal of our concessions.

We carry out our generation and distribution activities pursuant to concession agreements entered into with the Brazilian federal government. Our concessions range in duration from 17 to 35 years, with the first expiration date in 2015. CPFL Santa Cruz, CPFL Mococa, CPFL Sul Paulista, CPFL Leste Paulista and CPFL Jaguari hold a concession agreement to distribute electricity that expires in July 2015, with an option to renew for an additional 20 years.

The Brazilian constitution requires that all concessions relating to public services be awarded through a bidding process. In 1995, in an effort to implement these constitutional provisions, the federal government adopted certain laws and regulations, known collectively as the Concessions Law, governing bidding procedures in the electricity industry. In accordance with the Concessions Law, as modified by the New Industry Model Law, upon application by the concessionaire, existing concessions may be renewed by the federal government for additional periods of up to 30 years without being subject to the bidding process, provided that the concessionaire has met minimum performance standards and that the proposal is otherwise acceptable to the Federal Government.

In light of the degree of discretion granted to the federal government by the Concessions Law and the concession contracts with respect to renewal of existing concessions, and given the lack of long-standing precedents with respect to the federal government’s exercise of such discretion and interpretation and application of the Concessions Law, we cannot assure you that new concessions will be obtained or that concessions will be renewed on terms as favorable as those currently in effect. In addition, it is possible that our large industrial clients could be authorized by ANEEL to generate electric energy for self consumption or sale to third parties, in which case they may obtain an authorization or concession for the generation of electric power in a given area, which could adversely affect our results of operations.

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The tariffs that we charge for sales of electricity to captive consumers are determined by ANEEL pursuant to concession agreements with the Brazilian government, and our operating revenues could be adversely affected if ANEEL makes decisions relating to our tariffs that are not favorable to us.

ANEEL has substantial discretion to establish the tariff rates we charge our customers. Our tariffs are determined pursuant to concession agreements entered into with the Brazilian federal government, and in accordance with ANEEL’s regulations and decisions.

Our concession agreements and the Brazilian law establish a price cap mechanism that permits three types of tariff adjustments: (1) the annual adjustment (reajuste anual), (2) the periodic revision (revisão periódica) and (3) the extraordinary revision (revisão extraordinária). We are entitled to apply each year for the annual adjustment, which is designed to offset some effects of inflation on tariffs and pass through to customers certain changes in our cost structure that are beyond our control, such as the cost of electricity we purchase from certain sources and certain regulatory charges, including charges for the use of transmission and distribution facilities. In addition, ANEEL carries out a periodic revision every four or five years that is aimed at identifying variations in our costs as well as setting a factor based on our operational efficiency that will be applied against the index of our ongoing annual tariff adjustments, the objective of which is to share any related gains with our customers. We are also entitled to request an extraordinary revision of our tariffs if unpredictable costs significantly alter our cost structure.

We cannot be sure if ANEEL will establish tariffs at rates that are favorable to us, especially in the periodic revision process. In addition, to the extent that any of these adjustments are not granted by ANEEL in a timely manner, our financial condition and results of operations may be adversely affected. For more information on ANEEL, see “Item 4. Information on the Company—The Brazilian Power Industry—Principal Regulatory Authorities—ANEEL.”

We could be penalized by ANEEL for failing to comply with the terms of our concession agreements, which could result in fines, other penalties and, depending on the gravity of the non-compliance, in our concessions being terminated.

We carry out our generation and distribution activities pursuant to concession agreements entered into with the Brazilian government. ANEEL may impose penalties on us in the event that we fail to comply with any provision of our concession agreements. Depending on the gravity of the non-compliance, these penalties could include the following:

• warning notices;

• fines per breach of up to 2.0% of the concessionaire’s revenues in the year ended immediately prior to the date of the relevant breach;

• injunctions related to the construction of new facilities and equipment;

• restrictions on the operation of existing facilities and equipment;

• intervention by ANEEL in the management of the concessionaire; and

• termination of the concession.

In addition, the Brazilian government has the power to terminate any of our concessions prior to the end of the concession term in the case of bankruptcy or dissolution, or by means of expropriation for reasons related to the public interest.

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We are currently in compliance with all of the material terms of our concession agreements. However, we cannot assure you that we will not be penalized by ANEEL for breaching our concession agreements or that our concessions will not be terminated in the future. The compensation to which we are entitled upon termination of our concessions may not be sufficient for us to realize the full value of certain assets. If any of our concession agreements is terminated for reasons attributable to us, the effective amount of compensation by the granting authorities could be materially reduced through the imposition of fines or other penalties. Accordingly, the imposition of fines or penalties on us or the termination of any of our concessions could have a material adverse effect on our financial condition and results of operations.

We may not be able to fully pass through the costs of our electricity purchases and, to meet demand, we could be forced to enter into short-term agreements to purchase electricity at prices substantially higher than under our long-term purchase agreements.

Under the New Industry Model Law, an electricity distributor must contract in advance, through public bids, for 100% of its forecasted electricity needs for its distribution concession areas. If our forecasted demand is incorrect and we purchase less or more electricity than we need, we may be prevented from fully passing through the costs of our electricity purchases. For instance, the New Industry Model Law provides, among other restrictions, that if our forecasts fall significantly short of actual electricity demand, we may be forced to make up the shortfall with shorter term electricity purchase agreements. If our acquisitions of electricity in the public auctions are above the Annual Reference Value (Valor Anual de Referência) established by the Brazilian Government, we may not be able to fully pass through the costs of our electricity purchases. Our forecasted electricity demand may prove inaccurate, including as a result of customers moving between the different markets (regulated and free). If there are significant variations between our electricity needs and the volume of our electricity purchases, our results of operations may be adversely affected. See “Item 4. Information on the Company—The Brazilian Power Industry—The New Industry Model Law.”

ANEEL may limit distributions that our regulated subsidiaries may make to us.

The amounts that our regulated subsidiaries may distribute to us in the form of dividends in any given fiscal year depend on such subsidiaries making a profit, as calculated in accordance with Law No. 6,404 of December 15, 1976, as amended and supplemented, or Brazilian Corporate Law. Despite the significant cash flow generated by our regulated subsidiaries, their results are affected by the amortization of goodwill created upon the acquisition of RGE, Semesa and CPFL Jaguariúna and by depreciation. As a result, this limitation may eventually prevent some portion of the cash generated by our regulated subsidiaries from being distributed to us as dividends, and we would require approval by ANEEL to conduct a capital reduction.

We generate a significant portion of our operating revenues from customers that qualify as “potentially free” consumers, and who are allowed to seek alternative electricity suppliers upon the expiration of their contracts with us or by providing at least one year prior notice if their contract with us is for an undetermined period of time.

We hold concessions to distribute electricity in 300 of the 645 municipalities in the State of São Paulo, 262 of the 467 municipalities in the State of Rio Grande do Sul, 3 municipalities in the State of Paraná and 3 municipalities in the State of Minas Gerais. Within our concession areas, we do not face competition in the distribution of low voltage electricity to residential, commercial and industrial customers. However, other electricity suppliers are now permitted to compete with us in offering electricity to certain consumers that qualify as “potentially free” consumers, to whom our distribution subsidiaries may supply electricity only at regulated tariffs. Such potentially free consumers may elect to opt out of our regulated distribution system upon the expiration of their contracts with us, by providing a six months prior notice, or by providing an one year prior notice if their contract with us is valid for an undetermined period of time. At December 31, 2007, we supplied energy to 58 potentially free consumers, which accounted for approximately 3.1% of our net operating revenues and approximately 4.0% of the total volume of electricity sold by our distributors during 2007. In addition, other customers meeting certain criteria may become free consumers if they move to energy from renewable energy sources, such as Small Hydroelectric Power Plants or biomass. At December 31, 2007 we had a total of 1,464 of these customers that accounted for approximately 16.1% of our net operating revenues and approximately 18.9% of the total volume of electricity sold by our distribution subsidiaries during 2007. A decision by our potentially free consumers to become free consumers and purchase electricity from electricity suppliers serving free consumers located in our concession areas could adversely affect our market share and results of operations.

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Our operating results depend on prevailing hydrological conditions. The impact of an electricity shortage and related electricity rationing, as in 2001 and 2002, may have a material adverse effect on our business and results of operations.

We are dependent on the prevailing hydrological conditions in the geographic region in which we operate. In 2007, according to data from the National Electrical System Operator, Operador Nacional do Sistema Elétrico, or ONS, more than 92.8% of Brazil’s electricity supply came from hydroelectric generation facilities. Our region is subject to unpredictable hydrological conditions, with non-cyclical deviations from average rainfall. The most recent period of low rainfall was in the years prior to 2001, when the Brazilian government instituted the Rationing Program, a program to reduce electricity consumption that was in effect from June 1, 2001 to February 28, 2002. The Rationing Program established limits for energy consumption for industrial, commercial and residential consumers, which ranged from a 15% to a 25% reduction in energy consumption, and lasted from June 2001 until February 2002. If Brazil experiences another electricity shortage, the Brazilian government may implement similar or other policies in the future to address the shortage that could have a material adverse effect on our financial condition and results of operations. A recurrence of poor hydrological conditions that result in a low supply of electricity to the Brazilian market could cause, among other things, the implementation of broad electricity conservation programs, including mandated reductions in electricity consumption. We cannot assure you that periods of severe or sustained below-average rainfall will not adversely affect our future financial results.

Construction, expansion and operation of our electricity generation and distribution facilities and equipment involve significant risks that could lead to lost revenues or increased expenses.

The construction, expansion and operation of facilities and equipment for the generation and distribution of electricity involves many risks, including:

• the inability to obtain required governmental permits and approvals;

• the unavailability of equipment;

• supply interruptions;

• work stoppages;

• labor unrest;

• social unrest;

• weather and hydrological interferences;

• unforeseen engineering and environmental problems;

• increases in electricity losses, including technical and commercial losses;

• construction and operational delays, or unanticipated cost overruns; and

• unavailability of adequate funding.

If we experience these or other problems, we may not be able to generate and distribute electricity in amounts consistent with our projections, which may have an adverse effect on our financial condition and results of operations. We do not have insurance for many of these risks.

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Our equipment, facilities and operations are subject to numerous environmental and health regulations that may become more stringent in the future and may result in increased liabilities and increased capital expenditures.

Our distribution and generation activities are subject to comprehensive federal and state legislation as well as supervision by Brazilian governmental agencies that are responsible for the implementation of environmental and health laws and policies. These agencies could take enforcement action against us for our failure to comply with their regulations. These actions could include, among other things, the imposition of fines and revocation of licenses. It is possible that enhanced environmental and health regulations will force us to allocate capital expenditures towards compliance, and consequently, divert funds away from planned investments. Such a diversion could have a material adverse effect on our financial condition and results of operations.

If we are unable to complete our proposed capital expenditure program in a timely manner, the operation and development of our business may be adversely affected.

We plan to invest approximately R$951 million in our generation activities and R$3,885 million in our distribution activities during the period from 2008 through 2012. Our ability to carry out this capital expenditure program depends on a variety of factors, including our ability to charge adequate tariffs for our services, our access to domestic and international capital markets and a variety of operating, regulatory and other contingencies. We cannot be certain that we will have the financial resources to complete our proposed capital expenditure program, and failure to do so could have a material adverse effect on the operation and development of our business.

We are strictly liable for any damages resulting from inadequate rendering of electricity services, and our contracted insurance policies may not fully cover such damages.

Under Brazilian law we are strictly liable for direct and indirect damages resulting from the inadequate rendering of electricity distribution services. In addition, our distribution facilities may, together with our generation utilities, be held liable for damages caused to others as a result of interruptions or disturbances arising from the generation, transmission or distribution systems, whenever these interruptions or disturbances are not attributed to an identifiable member of the ONS.

We are controlled by a few shareholders acting together, and their interests could conflict with yours.

As of December 31, 2007, VBC Energia S.A., or VBC, 521 Participações S.A., or 521, and Bonaire Participações S.A., or Bonaire, owned 28.41%, 31.10% and 12.65%, respectively, of our outstanding common shares. These entities are parties to a shareholders’ agreement, pursuant to which they share the power to control us. Our controlling shareholders may take actions that could be contrary to your interests, and our controlling shareholders will be able to prevent other shareholders, including you, from blocking these actions. In particular, our controlling shareholders control the outcome of decisions at shareholders’ meetings, and they can elect a majority of the members of our Board of Directors. Our controlling shareholders can direct our actions in areas such as business strategy, financing, distributions, acquisitions and dispositions of assets or businesses. Their decisions on these matters may be contrary to the expectations or preferences of our minority shareholders, including holders of our ADSs. See “Item 7. Major Shareholders and Related Party Transactions— Shareholders’ Agreement.”

We are exposed to increases in prevailing market interest rates, as well as foreign exchange rate risk.

As of December 31, 2007, approximately 82.2% of our total indebtedness was denominated in reais and indexed to Brazilian money-market rates or inflation rates, or bore interest at floating rates. The remaining 17.8% of our total indebtedness was denominated in U.S. dollars and Japanese yen and substantially subject to currency swaps that converted these obligations into reais. Accordingly, if these indexation rates rise or the U.S. dollar/real or Japanese yen/real exchange rates appreciate, our financing expenses will increase.

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Our substantial leverage and debt service obligations could adversely affect our ability to operate our business and make payments on our debt.

We are highly leveraged and have significant debt service obligations. As of December 31, 2007, we had debt of R$6,090.9 million. Our substantial level of indebtedness increases the possibility that we may be unable to generate cash sufficient to pay when due the principal, interest or other amounts due in respect of our indebtedness. In addition, we may incur additional debt from time to time to finance strategic acquisitions, investments, joint ventures or for other purposes, subject to the restrictions applicable to our existing indebtedness. If we incur additional debt, the risks associated with our substantial leverage, including our ability to service our debt, would increase.

We may acquire other companies in the electricity business, as we have in the past, and these acquisitions will absorb our management’s time and may not result in increased operational efficiency.

We regularly analyze opportunities to acquire other companies engaged in activities along the entire electricity generation, transmission and distribution chain. If we do acquire other electricity companies, it will consume a portion of our management’s focus and could increase our leverage or reduce our profitability. Furthermore, we may not be able to integrate the acquired company’s activities and achieve the economies of scale and expected efficiency gains that often drive such acquisitions, and failure to do so could harm our financial condition and results of operations.

If we are unable to successfully control electricity losses, our results of operations could be adversely affected.

We experience two types of electricity losses: technical losses and commercial losses. Technical losses occur in the ordinary course of our distribution of electricity. Commercial losses result from illegal connections, fraud and underbilling. We cannot assure you that the strategies we have used will be effective in combating electricity losses. An increase in electricity losses could adversely affect our financial condition and results of operations.

Risks Relating to Brazil

The Brazilian government has exercised, and continues to exercise, significant influence over the Brazilian economy. This involvement, as well as Brazilian political and economic conditions, could adversely affect our business and the market price of the ADSs and our common shares.

The Brazilian government frequently intervenes in the Brazilian economy and occasionally makes significant changes in policy and regulations. The Brazilian government’s actions to control inflation and other policies and regulations have often involved, among other measures, price controls, currency devaluations, capital controls and limits on imports. Our business, financial condition and results of operations may be adversely affected by changes in policy or regulations involving or affecting exchange controls, as well as factors such as:

• currency fluctuations;

• inflation;

• interest rates;

• liquidity of domestic capital and lending markets;

• tax policies; and

• other political, social and economic developments in or affecting Brazil.

Uncertainties about future developments in the Brazilian economy may adversely affect us, our business, our results of operations and the market price of the ADSs and our common shares.

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Fluctuations in the value of the Brazilian real against foreign currencies may result in uncertainty in the Brazilian economy and the Brazilian securities market, and they could have a material adverse effect on our net income and cash flow.

In recent years, the Brazilian real has appreciated against foreign currencies, but the value of the real may continue to fluctuate and may rise or decline substantially from current levels. For additional information about historical exchange rates, see “Item 3. Key Information—Exchange Rates.”

Depreciation of the real would increase the cost of servicing our foreign currency-denominated debt and the cost of purchasing electricity from the Itaipu power plant, a hydroelectric facility that is one of our major suppliers and that adjusts electricity prices based in part on its U.S. dollar costs. Depreciation of the real would also create additional inflationary pressures in Brazil that may negatively affect us. Depreciation generally curtails access to international capital markets and may prompt government intervention, including recessionary governmental policies. It also reduces the U.S. dollar value of distributions and dividends on the ADSs and the U.S. dollar equivalent of the market price of our common shares and, as a result, the ADSs.

Inflation and efforts by the Brazilian government to combat inflation may contribute significantly to economic uncertainty in Brazil and could harm our business and the market price of the ADSs and our common shares.

Brazil has in the past experienced extremely high rates of inflation. More recently, Brazil’s annual rate of inflation was 1.2% in 2005, 3.8% in 2006 and 7.8% in 2007 as measured by the General Market Price Index (Índice Geral de Preços–Mercado, or IGP-M). Inflation, and certain government actions taken to combat inflation, has in the past had significant negative effects on the Brazilian economy. Measures to curb inflation, and speculation about possible future governmental measures, have contributed to economic uncertainty in Brazil and heightened volatility in the Brazilian securities markets.

Future measures taken by the Brazilian government, including interest rate changes, intervention in the foreign exchange market and actions to adjust or fix the value of the real may trigger increases in inflation, and consequently, have adverse economic impacts on our business. If Brazil experiences high inflation in the future, we may not be able to adjust the rates we charge our customers to offset the effects of inflation on our cost structure. Inflationary pressures may also hinder our ability to access foreign financial markets or lead to government policies to combat inflation that could harm our business or adversely affect the market price of the ADSs and our common shares.

The perception of risk in other countries, especially emerging market countries, may adversely affect the market price of Brazilian securities, including the ADSs and our common shares.

The market value of securities of Brazilian companies is affected to varying degrees by economic and market conditions in other countries, including other Latin American and emerging market countries. Although economic conditions in such countries may differ significantly from economic conditions in Brazil, investors’ reactions to developments in these other countries may have an adverse effect on the market value of securities of Brazilian issuers. Crises in other emerging market countries may hamper investor enthusiasm for securities of Brazilian issuers, including ours. This could adversely affect the market price of the ADSs or our common shares.

Risks Relating to the ADSs and Our Common Shares

Holders of our ADSs may encounter difficulties in the exercise of voting rights.

Holders of our common shares are entitled to vote on shareholder matters. You may encounter difficulties in the exercise of some of your rights as a shareholder if you hold our ADSs rather than the underlying common shares. For example, you are not entitled to attend a shareholders’ meeting, and you can only vote by giving timely instructions to the depositary in advance of the meeting.

If you surrender your ADSs and withdraw common shares, you risk losing the ability to remit foreign currency abroad and certain Brazilian tax advantages.

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As an ADS holder, you will benefit from the electronic certificate of foreign capital registration to be obtained by the custodian for our common shares underlying the ADSs in Brazil, which permits the custodian to convert dividends and other distributions with respect to the common shares into non-Brazilian currency and remit the proceeds abroad. If you surrender your ADSs and withdraw common shares, you will be entitled to continue to rely on the custodian’s electronic certificate of foreign capital registration for only five business days from the date of withdrawal. Thereafter, upon the disposition of or distributions relating to the common shares, you will not be able to remit abroad non-Brazilian currency unless you obtain your own electronic certificate of foreign capital registration or you qualify under Brazilian foreign investment regulations that entitle some foreign investors to buy and sell shares on Brazilian stock exchanges without obtaining separate electronic certificates of foreign capital registration. If you do not qualify under the foreign investment regulations you will generally be subject to less favorable tax treatment of dividends and distributions on, and the proceeds from any sale of, the common shares.

If you attempt to obtain your own electronic certificate of foreign capital registration, you may incur expenses or suffer delays in the application process, which could delay your ability to receive dividends or distributions relating to our common shares or the return of your capital in a timely manner. The depositary’s electronic certificate of foreign capital registration may also be adversely affected by future legislative changes.

The protections afforded to minority shareholders in Brazil are different from those in the United States, and may be more difficult to enforce.

Under Brazilian law, the protections afforded to minority shareholders are different from those in the United States. In particular, the legal framework with respect to shareholder disputes is less developed under Brazilian law than U.S. law and there are different procedural requirements for bringing shareholder lawsuits, such as shareholder derivative suits. As a result, in practice it may be more difficult for our minority shareholders to enforce their rights against us or our directors or controlling shareholders than it would be for shareholders of a U.S. company.

Changes in Brazilian tax laws may have an adverse impact on the taxes applicable to a disposition of the ADSs.

According to Law No. 10,833, enacted on December 29, 2003, the capital gains derived from the disposition of assets located in Brazil by a non-resident to either a Brazilian resident or a non-resident is subject to taxation in Brazil, regardless of whether the disposition occurs outside or within Brazil. If the disposition of assets is interpreted to include a disposition of the ADSs, this tax law could result in the imposition of withholding income tax on a disposition in Brazil of the ADSs by a non-resident of Brazil to another non-resident of Brazil. Because no judicial guidance as to the application of Law No. 10,833 yet exists, we are unable to predict whether an interpretation applying withholding income tax to dispositions of the ADSs between non-residents could ultimately prevail in the courts of Brazil. As a general rule, the capital gains derived from the disposition of common shares by a non-resident are subject to income tax in Brazil. See “Item 10. Additional Information-Taxation—Brazilian Tax Considerations.”

Holders of ADSs may be unable to exercise preemptive rights with respect to our common shares.

We may not be able to offer our common shares to U.S. holders of ADSs pursuant to preemptive rights granted to holders of our common shares in connection with any future issuance of our common shares unless a registration statement under the U.S. Securities Act of 1933, or the Securities Act, is effective with respect to such common shares and preemptive rights, or an exemption from the registration requirements of the Securities Act is available. We are not obligated to file a registration statement relating to preemptive rights with respect to our common shares, and we cannot assure you that we will file any such registration statement. If such a registration statement is not filed and an exemption from registration does not exist, The Bank of New York, as depositary, will attempt to sell the preemptive rights, and you will be entitled to receive the net proceeds of such sale. However, these preemptive rights will expire if the depositary does not sell them, and U.S. holders of ADSs will not realize any value from the granting of such preemptive rights.

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ITEM 4. INFORMATION ON THE COMPANY

Overview

We are a corporation (sociedade por ações) incorporated and existing under the laws of Brazil with the legal name CPFL Energia S.A. Our principal executive offices are located at Rua Gomes de Carvalho, 1,510, 14^º andar – Cj 1402, Vila Olímpia, CEP 04547-005, in the City of São Paulo, State of São Paulo, Brazil and our telephone number is +55 11 3841-8513.

We are a holding company that, through our subsidiaries, distributes, generates and commercializes electricity in Brazil. We were incorporated in 1998 as a joint venture among VBC, 521 and Bonaire to combine their interests in companies operating in the Brazilian power sector.

We are one of the largest electricity distributors in Brazil, based on the 35,245 GWh of electricity we distributed to approximately 6.3 million customers in 2007. In 2007, our installed generating capacity was 1,588 MW. We are also involved in upgrading existing generation assets, building three new hydroelectric generation facilities and upgrading two Small Hydroelectric Power Plants, through which we expect to increase our installed generating capacity to 2,174 MW as they are completed over the next 3 years.

We also engage in electricity commercialization and provide electricity-related services to our affiliates as well as unaffiliated parties. In 2007 the total amount of electricity sold by our commercialization services was 9,288 GWh and 9,128 GWh to afilliated and unaffiliated parties, respectively.

In 2007 and through April 2008, the following developments affected our corporate structure:

• In March 2007, in order to reduce administrative costs and simplify share structure, our subsidiaries CPFL Centrais Elétricas S.A. and Semesa S.A. were merged into CPFL Geração. This restructuring took effect retroactively beginning in January 2007.

• In March 2007, in connection with ANEEL regulations regarding segregation of corporate structure, CPFL Energia acquired share control of RGE from CPFL Paulista.

• In April 2007, we entered into a purchase agreement with CMS Electric & Gas, LLC to acquire 100% of the capital stock of CMS Energy Brasil S.A., for US$211.1 million. The acquisition closed in June 2007, after receiving regulatory approval from ANEEL, and CMS Energy Brasil S.A. changed its name to CPFL Jaguariúna. With the acquisition of CPFL Jaguariúna, we expanded our customer base by approximately 184,000 customers and our installed capacity by approximately 87 MW.

• In September 2007, in order to reduce administrative costs and simplify share structure, CPFL Serra Ltda., or CPFL Serra, was merged into Rio Grande Energia S.A., or RGE.

• In October 2007, in order to reduce administrative costs and simplify share structure, Nova 4 was merged into CPFL Santa Cruz.

• In December 2007 RGE became a wholly-owned subsidiary of CPFL Energia through a share exchange in which the shares of the minority shareholders of RGE were exchanged for shares of CPFL Energia. This transaction increased our share capital by R$ 6.4 million through the issuance of 154,208 common shares.

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The following chart provides an overview of our corporate structure, as of April 29, 2008:

Our core businesses are:

• Distribution. In 2007, our eight fully-consolidated distribution subsidiaries delivered 35,245 GWh of electricity to approximately 6.3 million customers primarily in the States of São Paulo and Rio Grande do Sul.

• Generation. As of December 31, 2007, we had installed generation capacity of 1,588 MW. During 2007 we generated a total of 6,382 GWh of electricity, and we had 6,698 GWh of Assured Energy, the amount of energy representing our long-term average electricity production, as established by ANEEL, which is the primary driver of our revenues relating to generation activities. We own an interest in the Serra da Mesa hydroelectric generation facility and are entitled to 51.54% of its Assured Energy. We also own and operate 32 Small Hydroelectric Power Plants and one thermoelectric power plant. Our UHE Campos Novos plant became fully operational in May 2007, and we own interests in three hydroelectric facilities currently under construction that we expect will be completed over the next three years. Once all of these facilities become fully operational, we estimate that our installed generation capacity will reach 2,174 MW. The increased capacity from the new generation facilities will principally be used for our own distribution and commercialization activities.

• Commercialization and Electricity-Related Services. Our subsidiary CPFL Comercialização Brasil S.A., or CPFL Brasil, handles our commercialization operations and electricity-related services. CPFL Brasil procures electricity for our distribution operations, sells electricity to free consumers, other commercialization companies and distribution utilities, and provides electricity-related services. In 2007, we sold 18,416 GWh of electricity of which 9,128 GWh was sold to unaffiliated third parties.

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Our Strategy

Our overall objective is to continue to be a leading supplier of electricity distribution services in Brazil, while expanding our other activities and maximizing profitability and shareholder value. We seek to achieve these goals by consistently pursuing operational efficiency, growth through business synergies, financial discipline, social responsibility and enhanced corporate governance standards. More specifically, our approach involves the following key business strategies:

Focus on further improving our operating efficiency. The distribution of electricity to captive customers in our distribution concession areas is our largest business segment. We continue to focus on improving our service and maintaining low operating costs by exploiting synergies across subsidiaries and investing in new systems that monitor our assets so that they are more efficiently managed. We seek to create value for our shareholders by optimizing our debt portfolio and exercising shrewd financial judgment. We also believe that a strong distribution business of sufficient scale will continue to provide a springboard for our strategies in electricity generation and commercialization. We also make an effort to standardize and update our operations regularly, introducing automated systems where possible.

Complete the development of our existing generation projects and expand our generation portfolio by developing new generation projects. We have been developing a portfolio of new hydroelectric generating facilities. In each of 2004, 2005 and 2007, one new facility became operational. Our generation capacity grew from 1,072 MW at the end of 2006 to 1,588 MW at the end of 2007. The Campos Novos plant became fully operational in May 2007. By the end of 2008, when our UHE Castro Alves plant and UHE 14 de Julho plants are scheduled to become fully operational, we expect our generation capacity to reach 1,738 MW. Each of these generation facilities has associated long-term power purchase agreements, or PPAs, approved by ANEEL, which we believe will ensure us an attractive rate of return on our investment. As per capita consumption of electricity in Brazil increases, we believe that there will continue to be new opportunities for us to explore investments in additional generation projects.

Expand and strengthen our commercialization business. Free consumers represent a significant segment of the electricity market in Brazil. We strive to maintain our captive market. However, where we face competition, we make an effort to retain those of our customers that are permitted to become free consumers by means of bilateral agreements with CPFL Brasil, our commercialization subsidiary, in addition to attracting additional free consumers from outside of our distribution companies’ concession areas. In order to achieve this objective, we foster positive relationships with customers by providing electricity-related services, strategic advice and decision-making support.

Position ourselves to take advantage of consolidation in our industry by using our experience in successfully integrating and restructuring other operations. We believe that with the stabilization of the regulatory environment in the Brazilian power industry, there may be substantial consolidation in the generation, the transmission and, particularly, the distribution sectors. Given our financial strength and managerial expertise, we believe that we are well-positioned to take advantage of this consolidation. If promising assets are available on attractive terms, we may make acquisitions that complement our existing operations and afford us further opportunities to take advantage of economies of scale.

Maintain a high level of social responsibility in the communities in which we operate. We aim to hold our business operations to the highest standards of social responsibility and sustainable development in terms of our efforts to respect the environment. We also support initiatives to advance the economic, cultural and social interests of the communities in which we operate and contribute effectively to their further development.

Follow enhanced corporate governance standards. We are dedicated to maintaining the highest levels of management transparency, provide equitable shareholder rights and, through various measures, including the increase of our free float and the liquidity of our shares, generate value for our shareholders.

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Our Service Territory

Distribution

We are one of the largest electricity distributors in Brazil, based on the amount of electricity we delivered in 2007. Our eight distribution subsidiaries together supply electricity to a region covering 208,205 square kilometers primarily in the States of São Paulo and Rio Grande do Sul. Their service areas include 568 municipalities and a population of approximately 17.6 million people. Together, they provided electricity to approximately 6.3 million customers as of December 31, 2007. Our eight subsidiaries distributed approximately 13.8% of the total electricity distributed in Brazil, based on the most recent data available from ANEEL.

Distribution Companies

We have eight distribution subsidiaries:

• CPFL Paulista. CPFL Paulista supplies electricity to a region covering 90,440 square kilometers in the State of São Paulo with a population of approximately 9.0 million people. Its service area covers 234 municipalities, including the cities of Campinas, Bauru, Ribeirão Preto,

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São José do Rio Preto, Araraquara and Piracicaba. CPFL Paulista had approximately 3.4 million customers as of December 31, 2007. In 2007, CPFL Paulista distributed 18,868 GWh of electricity, which accounts for approximately 16.4% of the total electricity distributed in the State of São Paulo, and 7.6% of the total electricity distributed in Brazil, during that period.

• CPFL Piratininga. CPFL Piratininga supplies electricity to a region covering 6,785 square kilometers in the southern part of the State of São Paulo with a population of approximately 3.6 million people. Its service area covers 27 municipalities, including the cities of Santos, Sorocaba and Jundiaí. CPFL Piratininga had approximately 1.3 million customers as of December 31, 2007. In 2007, CPFL Piratininga distributed 8,015 GWh of electricity, accounting for approximately 7.0% of the total electricity distributed in the State of São Paulo, and 3.0% of the total electricity distributed in Brazil, during that period.

• RGE. RGE supplies electricity to a region covering 90,718 square kilometers in the State of Rio Grande do Sul with a population of approximately 3.8 million people. Its service area covers 262 municipalities, including the cities of Caxias do Sul and Gravataí. RGE had approximately 1.2 million customers as of December 31, 2007. In 2007, RGE supplied 6,886 GWh of electricity (6,549 GWh distributed to final consumers, and 337 delivered principally to small electric concessionaires and small rural cooperatives), which accounts for approximately 31.9% of the total electricity distributed in the State of Rio Grande do Sul, and 2.4% of the total electricity distributed in Brazil during that period.

• CPFL Santa Cruz. CPFL Santa Cruz supplies electricity to an area covering 11,775 square kilometers, which includes 24 municipalities in the northwest part of the State of São Paulo and 3 municipalities in the State of Paraná. In 2007, CPFL Santa Cruz distributed 810 GWh of electricity to approximately 169,300 customers, accounting for approximately 0.6% of the total electricity distributed in the State of São Paulo, and 0.3% of the total electricity distributed in Brazil, during that period.

• CPFL Jaguari. Companhia Jaguari de Energia supplies electricity to an area covering 252 square kilometers, which includes 2 municipalities of the State of São Paulo. In 2007, CPFL Jaguari distributed 476 GWh of electricity (241 GWh of which we consolidated in CPFL Energia) to approximately 29,600 customers.

• CPFL Mococa. Companhia Luz e Força de Mococa supplies electricity to an area covering 1,844 square kilometers, which includes 1 municipality of the State of São Paulo and 3 municipalities in the State of Minas Gerais. In 2007, CPFL Mococa distributed 187 GWh of electricity (96 GWh of which we consolidated in CPFL Energia) to approximately 37,800 customers.

• CPFL Leste Paulista. Companhia Paulista de Energia Elétrica supplies electricity to an area covering 2,589 square kilometers, which includes 7 municipalities of the State of São Paulo. In 2007, CPFL Leste Paulista distributed 281 GWh of electricity (149 GWh of which we consolidated in CPFL Energia) to approximately 47,800 customers.

• CPFL Sul Paulista. Companhia Sul Paulista de Energia supplies electricity to an area covering 3,802 square kilometers, which includes 5 municipalities of the State of São Paulo. In 2007, CPFL Sul Paulista distributed 360 GWh of electricity (181 GWh of which we consolidated in CPFL Energia) to approximately 66,400 customers.

Distribution Network

Our eight distribution subsidiaries own distribution lines with voltage levels ranging from 34.5 kV to 138 kV. These lines distribute electricity from the connection point with the Basic Network to our power sub-stations, in each of our concession areas. All customers that connect to these distribution lines, such as free consumers or other concessionaires, are required to pay a tariff for using the system (tarifa de uso do sistema de distribuição, or TUSD).

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Each of our subsidiaries has a distribution network consisting of a widespread network of predominantly overhead lines and sub-stations having successively lower voltage ranges. Customers are classified in different voltage levels based on their consumption of, and demand for, electricity. Large industrial and commercial consumers receive electricity at high voltage ranges (up to 138 kV) while smaller industrial, commercial and residential customers receive electricity at lower voltage ranges (2.3 kV and below).

As of December 31, 2007, CPFL Energia’s distribution network consisted of 196,749 kilometers of distribution lines including 222,240 distribution transformers. Our eight distribution subsidiaries had 9,357 km of high voltage distribution lines between 34.5 kV and 138 kV. At that date, we had 424 transformer sub-stations for transforming high voltage into medium voltages for subsequent distribution, with total transforming capacity of 12,342 mega-volt amperes (MVA). Of CPFL Energia’s industrial and commercial customers, 199 had 69 kV or 138 kV high-voltage electricity supplied through direct connections to our high voltage distribution lines.

System Performance

Electricity Losses

We experience two types of electricity losses: technical losses and commercial losses. Technical losses are those that occur in the ordinary course of our distribution of electricity. Commercial losses are those that result from illegal connections, fraud or billing errors. Our electricity loss rates compare favorably to the average for other major Brazilian electricity distributors, which was 13.26% in 2006 according to the most recent information available from the Brazilian Association of Electric Energy Distributors (Associação Brasileira de Distribuidores de Energia Elétrica), or ABRADEE, an industry association.

We are also actively engaged in efforts to reduce commercial losses. To achieve this, in each of our eight subsidiaries, we have deployed trained technical teams to conduct inspections, enhanced monitoring for irregular consumption, increased replacements for obsolete measuring equipment and developed a computer program to discover and analyze irregular invoicing. Approximately 547,000 inspections were conducted during 2007, which we believe led to a recovery of receiveables estimated at more than R$140.6 million. Our eight distribution subsidiaries have lower rates of commercial losses than other Brazilian power companies.

Power Outages

The following table sets forth for each of our distribution subsidiaries the frequency and duration of electricity outages per customer for the year 2007:

		Year ended December 31, 2007
														CPFL
		CPFL		CPFL				CPFL		CPFL		CPFL		Leste		CPFL Sul
		Paulista		Piratininga		RGE		Santa Cruz		Jaguari		Mococa		Paulista		Paulista
FEC1		5.88		5.79		10.90		8.20		5.86		5.88		7.93		9.09
DEC2		6.98		6.90		17.04		5.85		6.32		4.25		6.80		11.58

We seek to improve the quality and reliability of our power supply, as measured by the frequency and duration of our power outages. Our frequency and duration of interruptions per costumer during 2007 compare favorably to the averages for other Brazilian distribution companies, which were 11.71 and 16.33 respectively. Based on data published by ANEEL, the duration and frequency of outages at CPFL Paulista and CPFL Piratininga are among the lowest in Brazil. The duration of outages at RGE are comparatively higher than those at CPFL Paulista and CPFL Piratininga, but they remain in line with the average rate for power companies in southern Brazil mainly as a result of the lack of redundancies in its distribution system, the use of medium voltage lines and a lower level of automation in the network. Moreover, these indicators at RGE are at historical lows for the company due principally to its corporate reorganization and maintenance policy.

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Our distribution subsidiaries have construction and maintenance technology that allows for repairs of the electricity network without interruption in electricity service, which allows us to have low levels of scheduled interruption, amounting to approximately 12% to 17% of total interruptions. Unscheduled interruptions due to accidents or natural causes, including lightning storms, fire and wind represented the remainder of our total interruptions. In 2007, we invested a total of R$253 million in materials, services and other related items to renovate and improve our distribution network to minimize both scheduled and unscheduled interruptions, and we expect to invest an additional R$285 million for such purposes in 2008.

We strive to improve response times for our repair services. The quality indicators for the provision of energy by CPFL Paulista and CPFL Piratininga have maintained levels of excellence while complying with regulatory standards. This was also mainly the result of our efficient operational logistics, including the strategic positioning of our teams and the technology and automation of our network and operation centers, together with a preventive maintenance and conservation plan.

Purchases of Electricity

Most of the electricity we sell is purchased from unrelated parties, rather than generated by our facilities. In 2007, 7.9% of the total electricity our distribution subsidiaries acquired was purchased from our generation subsidiaries. The following table summarizes the total electricity we purchased from Itaipu and others during the periods indicated.

		Year Ended December 31,
		2007				2006				2005
				Average				Average				Average
				Cost				Cost				Cost
		GWh		(R$/MWh)		GWh		(R$/MWh)		GWh		(R$/MWh)
Electricity purchases:
From Itaipu		10,990		R$89.44		10,761		R$82.34		10,501		R$84.17
From others		37,172		92.12		35,237		82.38		32,748		78.68
Total		48,162		91.51		45,998		82.37		43,249		80.01

Itaipu

We purchased 10,990 GWh of electricity in 2007 from the Itaipu power plant, amounting to 22.8% of the total electricity we purchased in 2007. Itaipu is located on the border of Brazil and Paraguay and is subject to a bilateral treaty between the two countries pursuant to which Brazil has committed to purchasing specified amounts of electricity. Electric utilities operating under concessions in the Midwest, South and Southeast regions of Brazil are required by law to purchase a portion of the electricity that Brazil is obligated to purchase from Itaipu. The amounts that these companies must purchase are governed by take-or-pay contracts with tariffs established in US$/kW. ANEEL annually determines the amount of electricity to be sold by Itaipu. We pay for energy purchased from Itaipu in accordance with the ratio between the volume established by ANEEL and our statutorily established share, regardless of whether Itaipu generates such amount of electricity. Our purchases represent approximately 12% of Itaipu’s total supply to Brazil. This share was fixed by law according to the amount of electricity sold in 1991. The rates at which companies are required to purchase Itaipu’s electricity are established pursuant to the bilateral treaty, and fixed to cover Itaipu’s operating expenses and payments of principal and interest on Itaipu’s U.S. dollar-denominated debts, as well as the cost of transmitting the power to their concession areas.

The Itaipu plant has an exclusive transmission grid. Distribution companies pay a fee for the use of this grid.

In 2007, we paid an average of R$89.44 per MWh for purchases of electricity from Itaipu, as compared to R$82.34 during 2006 and R$84.17 during 2005. These figures do not include the transmission fee.

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Other Suppliers

We purchased 37,172 GWh of electricity in 2007 from generating companies other than Itaipu, representing 77.2% of the total electricity we purchased. Of that amount, 50.3% was purchased in the regulated market and 49.7% was purchased in the free market. For more information on the regulated market and the free market, see “— The Brazilian Power Industry—The New Industry Model Law.”

The following table shows amounts purchased from suppliers other than Itaipu in the regulated market and in the free market, for the periods indicated.

		Year Ended December 31,
		2007		2006		2005
				(in GWh)
Electricity Purchased in the Regulated Market:
Tractebel Energia S.A		8,110		6,690		3,789
Petrobrás – Petróleo Brasileiro S.A.		1,717		1,717		1,769
AES Uruguaiana Ltda		1,244		1,119		834
Duke Energy Inter. Ger. Paranapanema S.A.		1,195		939		1,506
Furnas Centrais Elétricas S.A.		1,207		892		2,918
Electric Energy Trading Chamber — CCEE		783		520		507
Companhia de Geração de Energia Elétrica Tietê		377		387		1,218
Companhia Energética de São Paulo – CESP		1,071		372		2,556
Companhia Estadual de Energia Elétrica — CEEE		96		69		186
EMAE – Empresa Metropolitana de Águas e Energia S.A.		28		20		188
Other		2,856		1,739		985
Total		18,684		14,464		16,456
Electricity Purchased in the Free Market		18,488		20,773		16,292
Total		37,172		35,237		32,748

The provisions of our electricity supply contracts are governed by ANEEL regulations. The main provisions of each contract relate to the amount of electricity purchased, the price, including adjustments for various factors such as inflation indexes, and the duration of the contract.

Transmission Tariffs. In 2007, we paid a total of R$702.8 million in tariffs for the use of the transmission network, including Basic Network tariffs, connection tariffs and transmission of high-voltage electricity from Itaipu at rates set by ANEEL.

Customers and Tariffs

Customers

We classify our customers into five principal categories. See Note 23 to our audited consolidated financial statements for a breakdown of our sales by category.

• Industrial customers. Sales to final industrial customers accounted for 32.4% of our revenue of electricity sales in 2007.

• Residential customers. Sales to final residential customers accounted for 35.8% of our revenue of electricity sales in 2007.

• Commercial customers. Sales to final commercial customers, which include service businesses, universities and hospitals, accounted for 19.6% of our revenue of electricity sales in 2007.

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• Rural customers. Sales to final rural customers accounted for 3.8% of our revenue of electricity sales in 2007.

• Other customers. Sales to other customers, which include public and municipal services such as street lighting, accounted for 8.4% of our revenue of electricity sales in 2007.

Tariffs

Retail Distribution Tariffs. We classify our customers into two different groups, Group A customers and Group B customers, based on the voltage level at which the electricity is supplied to such customers. Each customer is placed in a certain tariff level defined by law and based on its respective classification, although some volume-based discounts are available. Group B customers pay higher tariffs. There are differentiated tariffs in Group B by types of customer (such as residential, commercial, rural and industrial). Customers in Group A pay lower tariffs, decreasing from A4 to Al, because they are supplied electricity at higher voltages, which requires lower use of the energy distribution system. Tariffs we charge for sales of electricity to final customers are determined pursuant to our concession agreements and regulations established by ANEEL. These concession agreements and related regulations establish a cap on tariffs that provides for annual, periodic and extraordinary adjustments. For a discussion of the regulatory regime applicable to our tariffs and their adjustment, see “—The Brazilian Power Industry.”

Group A customers receive electricity at 2.3 kV or higher. Tariffs for Group A customers are based on the voltage level at which electricity is supplied, and the time of year and the time of day electricity is supplied, although customers may opt for a differentiated tariff in peak periods. Tariffs for Group A customers are comprised of two components: a “capacity charge” and an “energy charge.” The capacity charge, expressed in reais per kW, is based on the higher of (1) contracted firm capacity or (2) power capacity actually used. The energy charge, expressed in reais per MWh, is based on the amount of electricity actually consumed. Group A customers are those that will likely qualify as free consumers under the New Industry Model Law.

Group B customers receive electricity at less than 2.3 kV (220V and 127V). Tariffs for Group B customers consist solely of an energy consumption charge and are based on the classification of the customer.

The following table sets forth our average retail prices for each customer category for 2007. These prices include taxes (ICMS, PIS and COFINS) and were calculated based on our revenues and the volume of eletricity sold in 2007.

							CPFL		CPFL
	CPFL		CPFL				Santa		Leste		CPFL Sul		CPFL		CPFL
	Paulista		Piratininga		RGE		Cruz		Paulista		Paulista		Jaguari		Mococa
							(R$/MWh)
Residential	424.00		407.24		445.03		423.83		454.10		427.36		346.80		499.59
Industrial	321.51		302.53		320.48		356.99		295.89		265.50		233.05		305.53
Commercial	372.46		379.42		446.26		430.12		428.98		445.32		316.13		438.83
Rural	210.37		182.83		178.06		163.09		224.95		235.28		125.56		245.94
Other	275.66		277.71		328.31		294.35		281.82		291.28		248.17		304.55
Total	352.95		347.14		348.99		336.25		330.69		329.37		234.11		367.99

Under current regulations, a low income residential customer is any single phase customer who (i) consumes less than 80 kWh per month, (ii) has not had electricity consumption of more than 120 kWh per month more than twice during any previous twelve-month period or (iii) consumed between 80 kWh and 220 kWh on a monthly basis within the previous twelve months and has filed an application to receive benefits under any of the Brazilian government’s social programs. Low-income residential customers are considered a subgroup of residential customers and are not subject to payment of emergency capacity and emergency acquisition charges or any extraordinary tariff approved by ANEEL.

TUSD. Under applicable laws and regulations, we are required to allow use of our high-voltage distribution lines by others, including free consumers within our distribution concession areas that are supplied by third parties. All of our customers must pay a fee for the use of our network. In 2007, tariff revenues for the use of our network by free consumers amounted to R$799.6 million. The average tariff for the use of our network was R$71.21 MWh in 2007, including the TUSD we charge to other distributors connected to our distribution network.

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Billing Procedures

The procedure we use for billing and payment for electricity supplied to our customers is determined by customer category. Meter readings and invoicing take place on a monthly basis for low voltage consumers, with the exception of rural consumers whose meters are read in intervals varying from one to three months, as authorized by relevant regulation. Bills are prepared from meter readings or on the basis of estimated usage. Low voltage customers are billed within three business days after the meter reading, with payment required within five business days after the invoice date. In case of nonpayment, a notification of nonpayment accompanied by the next month’s invoice, is sent to the customer and a period of 15 days is provided to eliminate the amount owed to us. If payment is not received within three business days after the 15-day period, the customers’ electricity supply is suspended.

High voltage customers are billed on a monthly basis with payment required within five business days after the invoice date. In the event of non-payment, a notice is sent to the customer four business days after the due date, giving a deadline of 15 days to make payment. If payment is not made within three business days after the notice, the customer is subject to discontinuation of service.

At December 31, 2007, customers in default represented in average 1.49% of annual revenues of our eight subsidiaries. These figures have fallen consistently in the past few years and currently are among the lowest in the Brazilian power industry.

Customer Service

We strive to provide high-quality customer service to our distribution customers. We operate call centers at each of our distribution subsidiaries providing customer service 24 hours a day, 7 days a week. In 2007, our call centers responded to more than 11.5 million calls. We also provide customer service through our Internet website, which handled approximately 4.7 million customer requests in 2007, and through our branch offices, which handled approximately 1.3 million customer requests in 2007. The growth in electronic requests has allowed us to reduce our customer service costs. Following receipt of a customer service request, we dispatch our technicians to make any necessary repairs.

Generation of Electricity

We are actively expanding our generating capacity. In accordance with Brazilian regulation, revenues from generation are based mainly on Assured Energy of each facility, rather than its installed capacity or actual output of each generating facility. Assured Energy is a fixed output of electricity established by the Brazilian government in the relevant concession agreement. Actual output is determined periodically by the ONS in view of demand and hydrological conditions. Provided generators have sold their electricity, they will receive at least the amount relating to the Assured Energy, even if they do not actually generate all of it. Conversely, in case the generators’ output exceeds the Assured Energy their incremental revenue will only cover the costs associated thereto.

In 2007, CPFL Geração owned 51.54% interest in the Assured Energy from the Serra da Mesa power plant. Through our generation subsidiaries CERAN, BAESA and ENERCAN, CPFL Geração also owned interests in the Monte Claro, Barra Grande and Campos Novos plants, which have been operational since December 2004, November 2005 and February 2007, respectively. Through the recently acquired CPFL Jaguariúna, we owned 6.93% interest in the Luis Eduardo Magalhães power plant. We also operated 32 Small Hydroelectric Power Plants and one thermoelectric plant.

Our total installed generation capacity from all of these facilities was 1,588 MW as of December 31, 2007. We produce electricity almost exclusively through our hydroelectric plants. We generated 6,382 GWh in 2007, 3,407 GWh in 2006, and 3,126 GWh in 2005. We are also currently involved in joint ventures to build three new hydroelectric generation facilities, Castro Alves, 14 de Julho and Foz do Chapecó. We are also renovating existing facilities in order to increase our total installed generation capacity to 2,174 MW by 2010.

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As part of our strategy to reduce administrative costs and simplify our corporate structure in order to increase our competitiveness, in March 2007 CPFL Centrais Elétricas and Semesa were fully merged into CPFL Geração.

Most of our hydroelectric plants are members of the Energy Reallocation Mechanism (Mecanismo de Realocação de Energia, or MRE), which mitigates hydrologic risks. MRE’s main purpose is to assure that all the participant power plants receive their level of Assured Energy, regardless of their actual levels of electricity generation. In other words, MRE reallocates energy, transferring excess electricity from those plants that generated more than their Assured Energy to those that generated a lower level.

The following table sets forth certain information relating to our principal facilities in operation as of December 31, 2007.

CPFL Geração Plants

		Installed		Assured		Placed in		Facility		Concession
		Capacity		Energy		Service		Upgraded		Expires
		(MW)		(GWh/year)
Hydroelectric plants:
Serra da Mesa		1,275.0		5,878.0		1998				(1)
Our share of Serra da Mesa (51.54%)		657.1		3,029.5
Monte Claro		130.0		516.8		2004				2036
Our share of Monte Claro (65%)		84.5		335.9
Barra Grande		690.0		3,334.1		2005				2036
Our share of Barra Grande (25%)		172.5		833.7
Campos Novos		880.0		3,310.4		2007				2035
Our share of Campos Novos (48.72%)		428.8		1,612.9
Americana		30.0		78.8		1949		2002		2027
Andorinhas		0.5		4.0		1937		(2)		(4)
Buritis		0.8		7.9		1922				2027
Capão Preto		5.5		8.7		1911		(2)		2027
Cariobinha		1.3		0		1936		(2 and 3)		2027
Chibarro		2.6		14.8		1912		2007		2027
Dourados		10.8		68.0		1926		2002		2027
Eloy Chaves		19.0		106.9		1954		1993		2027
Esmeril		5.0		25.2		1912		2003		2027
Gavião Peixoto		4.8		33.5		1913		2007		2027
Guaporé		0.7		5.4		1950		(2)		(4)
Jaguari		11.8		78.8		1917		2002		2027
Lençóis		1.7		14.7		1917		1988		2027
Monjolinho		0.6		2.7		1893		2003		2027
Pinhal		6.8		32.4		1928		1993		2027
Pirapó		0.7		5.6		1952				(4)
Saltinho		0.8		6.4		1950				(4)
Salto do Pinhal		0.6		0		1911		(3)		2027
Salto Grande		4.6		23.8		1912		2003		2027
Santana		4.3		25.4		1951		2002		2027
São Joaquim		8.1		49.3		1911		2002		2027
Socorro		1.0		5.3		1909		1994		2027
Três Saltos		0.7		5.3		1928		(2)		2027
Thermoelectric plants:
Carioba		36.0		219.0		1954				2027
Sub-total		1,501.6		6,633.9

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CPFL Jaguariuna Plants

		Installed		Assured		Placed in		Facility		Concession
		Capacity		Energy		Service		Upgraded		Expires
		(MW)		(GWh/year)
Hydroelectric plants:
Lavrinha		0.3		(5)		1947				(4)
Macaco Branco		2.4		(5)		1911				2015
Pinheirinho		0.6		(5)		1911				(4)
Rio do Peixe I		3.1		(5)		1925				2015
Rio do Peixe II		15.0		(5)		1998				2015
Santa Alice		0.6		(5)		1907				(4)
São José		0.8		(5)		1934				(4)
São Sebastião		0.7		(5)		1925				(4)
Turvinho		0.8		(5)		1912				(4)
Luis Eduardo Magalhães		902.5		4,613.0		2001				2032
Our share of Luis Eduardo Magalhães (6.93%)		62.5		319.7
Sub-total		86.8		319.7
Total		1,588

Serra da Mesa. Our largest hydroelectric facility in operation is the Serra da Mesa facility, which we acquired in 2001 from VBC, one of our controlling shareholders. Furnas began construction on the Serra da Mesa facility in 1985. In 1994, construction was suspended due to a lack of resources, which led to a public bidding procedure in order to resume construction. Serra da Mesa currently consists of three hydroelectric facilities located on the Tocantins River in the State of Goiás. The Serra da Mesa facility began operations in 1998 and has an installed capacity of 1,275 MW. The concession for the Serra da Mesa facility is owned by Furnas, which is also the operator, and we own part of the facility. Under Furnas’ rental agreement with us, which has a 30-year term commencing in 1998, we have the right to 51.54% of the Assured Energy of the Serra da Mesa facility until 2028, irrespective of the actual electricity produced by the facility, even if, during the term of the concession, there is an expropriation or forfeiture of the concession or the term of the concession expires. We sell all of such electricity to Furnas under an electricity purchase contract that expires in 2014 and that adjusts annually based on the IGP-M. After the expiration of this electricity purchase arrangement with Furnas, we will retain, until 2028, the right to 51.54% of the Assured Energy of Serra da Mesa. We will be allowed to commercialize it in accordance with regulations applicable at such time. Our share of the installed capacity and Assured Energy of the Serra da Mesa facility is 657 MW and 3,030 GWh/year, respectively.

Monte Claro. In 2004, Monte Claro’s first generator became operational, with an installed capacity of 65 MW and Assured Energy of 509.8 GWh a year, and in 2006, the second generator become operational, with an installed capacity of 65 MW and Assured Energy of 7.0 GWh per year. The plant, which belongs to the CERAN Complex, in which CPFL Geração holds a 65% ownership interest, now has a total of 130 MW in installed capacity and 516.8 GWh in Assured Energy per year.

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Barra Grande. This facility became fully operational on May 1, 2006 with a total installed capacity of 690 MW and total Assured Energy of 3,334.1 GWh per year. CPFL Geração owns a 25.01% interested in this project. The other shareholders of the joint venture are Alcoa (42.18%), CBA – Companhia Brasileira de Alumínio (15.00%), DME – Departamento Municipal de Eletricidade de Poços de Caldas (8.82%), and Camargo Corrêa Cimentos S.A. (9.00%).

Campos Novos. We own a 48.72% interest in ENERCAN, a joint venture formed by a consortium of private and public sector companies that was granted a 35-year concession in May 2000 to construct, finance and operate the Campos Novos hydroelectric facility. The plant was constructed on the Canoas River in the State of Santa Catarina, and became fully operational on May 1^st, 2007 with a total installed capacity of 880 MW and Assured Energy of 3,310.4 GWh per year, of which our interest is 1,612.9 GWh per year. The other shareholders of ENERCAN are CBA (24.73%), Votorantim Metais Níqueis S.A. (20.04%) and CEEE – Companhia Estadual de Energia Elétrica (6.51%) . The plant is operated by ENERCAN under CPFL Geração’s supervision. This plant increased our installed capacity by 428,8 MW.

Luis Eduardo Magalhães Power Plant. We own a 6.93% interest in Luis Eduardo Magalhães power plant, also known as UHE Lajeado. The plant is located on the Tocantins river in the State of Tocantins, and became fully operational in November, 2002 with a total installed capacity of 902.5 MW and assured energy of 4,613 GWh per year. The plant was built by Investco S.A., a consortium formed by Group REDE, EDP (Energias de Portugal), CEB (Companhia Energética de Brasília) and CMS Energy (that we acquired in 2007).

Small Hydroelectric Power Plants. We operate 32 Small Hydroelectric Power Plants. Since 1988, we have been investing in their renovation and automation to increase their output. The program basically consists of the substitution of generation units by means of increase of power, replacing existing turbines and upgrading peripheral equipment and automated systems, as well as restoring infrastructure. Through these initiatives we hope to increase the Assured Energy of such plants, their production of electricity and our profitability, while minimizing operational costs.

The automation of these power plants permits the remote execution of their control, supervision and operations. We also created an operations center for the management and monitoring of our power plants in Campinas, making it possible for the entire production cycle of the power plants to be remotely controlled in real time.

The costs of operations and maintenance of CPFL Geração’s plants decreased from R$26.47/MWh in 1997 to R$11.37/MWh in 2007. The rate of availability of our power generation equipment increased from 82% in 1997 to 97% in 2007. During 2008, we expect to begin projects to refurbish four power plants: Três Saltos, Andorinhas, Guaporé and Cariobinha.

In 2004, modernizing projects were presented for Gavião Peixoto, Chibarro and Capão Preto. The Gavião Peixoto project was approved by ANEEL in July of 2004 and the new Assured Energy level was approved by the Ministry of Mines and Energy – MME in June 2005, thereby increasing from 19.3 GWh per year to 33.5 GWh per year. Work on this project began in August 2005. The first generator began commercial operations in June 2007 and renovation projects were completed in July 2007. The renovation projects at the Capão Preto and Chibarro plants were approved by ANEEL in August and September 2005, respectively. The MME approved an increase in Assured Energy at Capão Preto from 8.7 GWh per year to 19.9 GWh per year, and at Chibarro from 6.1 GWh per year to 14.8 GWh per year. The modernization and renovation of these plants began in October 2006. Chibarro was completed in December 2007 and Capão Preto was completed in February 2008.

Thermoelectric Plants. We operate one thermoelectric power plant with an installed capacity of 36 MW. The Carioba facility was constructed in 1954. As of 2002, the Carioba facility was operating with 100% fuel-subsidized oil. Beginning in 2003, this subsidy was gradually reduced and contracted electricity was simultaneously decreased by 25% per year. By the end of 2006, the subsidy was phased out entirely and, as a result, all assured energy at Carioba is now available to be contracted pursuant to PPAs.

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Expansion of Generation Capacity

Demand for electricity in our distribution concession areas continues to grow. To address this increase in demand, and to improve our margins, we are expanding our generation capacity. We are currently involved in the construction of three new hydroelectric generation facilities with a total expected installed capacity of 1,085 MW, of which our share will be 585.6 MW. By the end of 2008, we expect that approximately 26% of the generating capacity from these facilities will become operational.

The following table sets forth information regarding our current hydroelectric generation projects as of December 31, 2007.

	Estimated  Installed  Capacity		Estimated  Assured  Energy		Estimated  Construction  Cost 1)		Start of  Construction		Expected  Start of  Operations		Our  Ownership		Estimated  Installed  Capacity  Available  to us		Estimated  Assured Energy  Available to us
	(MW)		(GWh/yr)		(R$million)						(%)		(MW)		(GWh/yr)
CERAN Complex:
Castro Alves	130		560.6		429.9		April 2004		2008		65.00		84.5		364.4
14 de Julho	100		438.0		428.8		October 2004		2008		65.00		65.0		284.7
	230		998.6		858.7								149.5		649.1
Foz do Chapecó	855		3,784.3		2,262.4		December 2006		2010		51.00		436.1		1,930.1
Total	1,085		4,782.9		3,121.1								585.6		2,579.2

CERAN Project. We own a 65% interest in CERAN, a joint venture that was granted a 35-year concession in March 2001 to construct, finance and operate the CERAN hydroelectric complex. The other shareholders are CEEE (30%) and Desenvix (5%). The CERAN hydroelectric complex consists of three hydroelectric plants: Monte Claro, Castro Alves and 14 de Julho. The complex is located on the Antas River approximately 120 km north of Porto Alegre, near the city of Bento Gonçalves, in the State of Rio Grande do Sul. The total cost of constructing the complex is estimated at R$1,229.1 million, of which we will be responsible for R$798.9 million. The Monte Claro plant began operations in December 2004 and is currently operating at full capacity. The first and second generators of the Castro Alves plant began commercial operations in March and April 2008, respectively, and the plant is projected to be operating at full capacity in the first half of 2008. The entire CERAN Complex will be fully operational in 2008, when UHE 14 de Julho becomes operational.

The facility will have estimated installed capacity of 360 MW and estimated Assured Energy of 1,515.5 GWh per year, of which our share will be 985.1 GWh/year. Upon completion, the facility will be operated by CERAN under CPFL Geração’s supervision. We anticipate that the plant will add 234 MW to our generation capacity.

In February 2004, CERAN entered into a loan agreement with BNDES in the amount of R$435.8 million. In January 2007, this agreement was amended for an additional disbursement of R$ 180 million. We have provided a 100% guarantee of the construction costs for the CERAN complex. The financing is also secured by a pledge of (i) the shares of CERAN and (ii) the rights of CERAN under its concession agreement to operate the hydroelectric plant, including credit rights from the sale of energy, guarantees in connection with energy purchase agreements, amounts paid by ANEEL as indemnity for the termination of the concession and electricity produced by CERAN. As of December 31, 2007, the total estimated cost to complete the facility was R$97.2 million.

Foz do Chapecó Project. We own a 51% interest in Foz do Chapecó, a joint venture that plans to construct, finance and operate the Foz do Chapecó hydroelectric plant pursuant to a 35-year concession granted in November 2001. The remaining 49% interest in the joint venture is divided among Chapecoense Geração de Energia S.A., which holds a 40% interest, and CEEE, which holds a 9% interest. The Foz do Chapecó hydroelectric plant will be located on the Uruguay River, on the border between the states of Santa Catarina and Rio Grande do Sul. The total estimated construction cost of the facility is estimated at R$2,262.4 million, of which we will be responsible for R$1,153.8 million. Construction began in December 2006, and we anticipate that the plant will begin operations in 2010 and will add 436 MW to our generation capacity.

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The expected capital structure is 26.0% equity and 74.0% debt. Foz do Chapecó obtained R$1,655.84 million of financing for the Foz do Chapecó Project from BNDES. During 2007, the first disbursement was made in the total amount of R$480.0 million. CPFL Energia will be the guarantor for CPFL Geração’s portion in the financing. The financing is also secured by a pledge of (i) the shares of Foz do Chapecó and (ii) credit rights of Foz do Chapecó related to the concession.

Electricity Commercialization and Services

Commercialization Operations

CPFL Brasil carries out our electricity commercialization operations. Its key functions are:

• procuring electricity for commercialization activities by entering into bilateral contracts with generating companies (including our generation subsidiaries) and purchasing electricity in public auctions from generation companies;

• reselling electricity to free consumers;

• reselling electricity to distribution companies (including CPFL Paulista, CPFL Piratininga and RGE) and other agents in the electricity market through bilateral contracts; and

• providing electricity-related services and consulting to final customers and other agents.

The rates at which CPFL Brasil purchases and sells electricity in the free market are determined in bilateral negotiations with its suppliers and customers. The contracts with distribution companies are regulated by ANEEL. In addition to marketing electricity to unaffiliated parties, CPFL Brasil resells electricity to CPFL Paulista, CPFL Piratininga and RGE, but profit margins from sales to related parties have been limited to an average of 10% by ANEEL regulations. Prior to the New Industry Model Law, distribution companies were permitted to purchase up to 30% of their electricity requirements from affiliated companies. The ability to sell electricity to affiliated companies has been eliminated under the New Industry Model Law, with the exception of those contracts approved by ANEEL prior to March 2004. However we are allowed to sell electricity to distributors through the open bidding process in the Regulated Market.

Electricity-Related Services

We offer our customers a wide range of electricity-related services through CPFL Brasil. These services are designed to help customers improve the efficiency, cost and reliability of the electric equipment they use. Our main electricity-related services include:

• Electric energy management consultancy: CPFL Brasil’s consultancy and contract management services aim to support its customers’ decision-making with respect to electrical power;

• Project design and construction: CPFL Brasil plans, constructs, commissions and provides electricity to substations, transmission lines, transformer stations, load centers and electrical energy distribution lines, always in line with each customer’s needs and growth expectations and in accordance with the most rigorous safety criteria, aiming for an optimal use of resources;

• Management of assets: In the maintenance arena, CPFL Brasil develops solutions that contribute to the optimal operation of electro-energetic installations for companies of all sizes, ensuring that interruptions to the electrical energy supply, and resulting business losses, are minimized;

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• Energy efficiency: CPFL Brasil aims to guide and assist its customers’ businesses with the most energy efficient solutions, leading to reduced energy costs and allowing for greater investments in core business pursuits;

• Co-generation: Energy co-generation is the simultaneous and sequential production of two or more forms of energy from a single fuel; the most common process is electrical energy production from primary energy sources (natural gas and/or biomass). Companies with production processes, which make the installation of such a system feasible, can count on CPFL Brasil’s experience for feasibility studies, project design and installation of co-generation operations.

Competition

We face competition from other generation and commercialization companies for distribution of electricity to free consumers. Distribution and transmission companies are required to permit the use of their lines and ancillary facilities for the distribution and transmission of electricity by other parties upon payment of a tariff.

Brazilian law provides that all of our concessions can be renewed once with approval from MME or ANEEL as the granting authority, provided that the concessionaire so requests and that certain requirements related to the rendering of public services are met. We intend to apply for the extension of each concession upon its expiration. We may face significant competition from third parties in bidding for renewal of such concessions or for any new concessions. ANEEL has absolute discretion over whether to renew existing concessions, and the acquisition of certain concessions by competing investors could adversely affect our results of operations.

Our Concessions

We operate under concessions granted by the Brazilian government through ANEEL for our generation and distribution businesses. We have the following concessions with respect to our distribution business:

Concession No.		Concessionaire		State		Term
014/1997		CPFL Paulista		São Paulo		30 years from November 20, 1997
09/2002		CPFL Piratininga		São Paulo		30 years from October 23, 1998
013/1997		RGE		Rio Grande do Sul		30 years from November 6, 1997
021/1999		Companhia Luz e Força Santa Cruz		São Paulo and Paraná		16 years from February 3, 1999 to July 7, 2015
015/1999		Companhia Jaguari de Energia		São Paulo		16 years from February 3, 1999 to July 7, 2015
017/1999		Companhia Luz e Força de Mococa		São Paulo e Minas Gerais		16 years from February 3, 1999 to July 7, 2015
018/1999		Companhia Paulista Energia Elétrica		São Paulo		16 years from February 3, 1999 to July 7, 2015
019/1999		Companhia Sul Paulista de Energia		São Paulo		16 years from February 3, 1999 to July 7, 2015

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Our generation business is supported by the following concessions:

Concession No.		Concessionaire		Plant		State		Term
128/2001		Foz do Chapecó Energia S.A.		Foz do Chapecó		Santa Catarina, Rio		35 years from November 7, 2001
						Grande do Sul
036/2001		Energética Barra Grande S.A.		Barra Grande		Rio Grande do Sul		35 years from May 14, 2001
008/2001		Companhia Energética Rio		14 Julho, Castro Alves and		Rio Grande do Sul		35 years from March 3, 2001
		das Antas		Monte Claro
043/2000		Campos Novos Energia S.A.		Campos Novos		Santa Catarina		35 years from May 29, 2000
015/1997		CPFL Geração		Our 19 Small Hydroelectric		São Paulo		30 years from November 20, 1997
				Power Plants and one
				thermoelectric facility
Decree N°		CPFL Geração		Serra da Mesa		Goiás		(1)
85,983/81
05/1997		Investco S.A. and Paulista		Luis Eduardo Magalhães		Tocantins		35 years from December 16, 1997
		Lajeado Energia S.A.
09/1999		Companhia Jaguari de		Macaco Branco (Small		São Paulo		16 years from February 3, 1999 to
		Energia		Hydroelectric Power Plant)				July 7, 2015
10/1999		Companhia Paulista de		Rio do Peixe I and II (Small		São Paulo		16 years from February 3, 1999 to
		Energia Elétrica		Hydroelectric Power Plant)				July 7, 2015

Properties

Our principal properties consist of hydroelectric generation plants, substations and distribution networks. The net book value of our total property, plant and equipment as of December 31, 2007 was R$7,140 million. Apart from our distribution network, no single one of our properties produces more than 10% of our total revenues. Our facilities are generally adequate for our present needs and suitable for their intended purposes.

Pursuant to Brazilian law, essential properties and facilities used by us to perform our obligations under our concession agreements cannot be transferred, assigned, pledged or sold to, or encumbered by, any of our creditors without prior approval from ANEEL.

Environmental

The Brazilian constitution gives both the Brazilian Federal and State Governments the power to enact laws designed to protect the environment. A similar power is given to municipalities whose local interests may be affected. Municipal laws are considered a supplement to federal and state laws. A violator of applicable environmental laws may be subject to administrative and criminal sanctions, and will have an obligation to repair and/or provide compensation for environmental damages. Administrative sanctions may include substantial fines and suspension of activities, while criminal sanctions may include fines and, for individuals, possible imprisonment, which can be imposed against executive officers and employees of companies who commit environmental crimes.

Our energy distribution and generation facilities are subject to environmental licensing procedures, which include the preparation of environmental impact assessments before such facilities are constructed. Once the respective environmental licenses are obtained, their maintenance is still subject to the compliance with various specific requirements.

The environmental issues regarding the construction of our new electricity generation facilities require specially-tailored oversight. For this reason, CPFL Geração manages these matters along with the basic environmental needs of each site in order to ensure that its policies and its environmental obligations are given adequate consideration. Decisions are made by environmental committees, whose members include representatives of each project partner and of each plant’s environmental management office. In this way, the implementation of environmental projects and the interaction with government agencies are given more importance in the process of environmental compliance and future electricity generation. For example, in securing the operating license for Barra Grande from IBAMA in July 2005, the project managers had a productive dialogue with representatives from the federal government allowing for both expanded electricity generation and environmental preservation. In addition, we support local community programs that relocate rural families from collective resettlements and provide institutional support for families involved in the conservation of the local biodiversity.

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In order to facilitate compliance with environmental laws, we use an environmental management system that was implemented in all of our segments and follows the standards of ISO 14001. We established a system to identify, evaluate and update with respect to applicable environmental laws, as well as other requirements applicable to our environmental management system. Our generation and distribution of electricity is submitted to internal and external audits, which verify if our activities are in compliance with ISO 14001. The environmental management of our activities is developed taking into consideration our budgets and realistic forecasts, always aiming to achieve better financial, social and environmental results.

The complex environmental licensing process is being reviewed by the Brazilian government with the cooperation of private sector companies, including us, with a view to expediting the procedures for the granting of licenses for the installation and the operation of infrastructure works that are necessary for the social and economic development of Brazil.

THE BRAZILIAN POWER INDUSTRY

General

In 2008, the MME (defined below) approved a ten-year expansion plan under which Brazil’s installed power generation capacity is projected to increase to 144.8 GW by 2016, of which 115.0 GW (79.4%) is projected to be hydroelectric, 29.8 GW (20.6%) is projected to be thermoelectric and 8.6 GW (6.6%) is projected to be imported through the Interconnected Power System.

In 2007, Eletrobrás owned 39% of Brazilian generation assets. Through its subsidiaries, Eletrobrás is also responsible for 66% of Brazil’s installed transmission capacity above 230 kV. In addition, it has participation in some Brazilian state-controlled entities involved in the generation, transmission and distribution of electricity. They include, among others, Companhia Hidroelétrica do São Francisco — CHESF and Furnas Centrais Elétricas S.A.

Private companies had 40% and 71% of the market for generation and distribution activities, in terms of total capacity and demand, respectively, and 24% of the transmission market, in terms of revenue.

Principal Regulatory Authorities

Ministry of Mines and Energy — MME

The MME is the Brazilian government’s primary regulator of the power industry. Following the adoption of the New Industry Model Law, the Brazilian government, acting primarily through the MME, has undertaken certain duties that were previously the responsibility of ANEEL, including the drafting of the guidelines governing the granting of concessions and the issuance of directives governing the bidding process for concessions relating to public services and public assets.

National Energy Policy Council

The National Energy Policy Council (Conselho Nacional de Política Energética), or CNPE, is a committee created in August 1997 to advise the Brazilian President with respect to the development of the national energy policy. The Brazilian Minister of Mines and Energy is the Chairman of the CNPE, six of its members are ministers of the Brazilian government and three of its members are selected by the Brazilian President. The CNPE was created to optimize the use of Brazil’s energy resources and to ensure the supply of energy to the country.

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ANEEL

ANEEL is an independent federal regulatory agency whose primary responsibility is to regulate and supervise the power industry in accordance with the policies set forth by the MME and to respond to matters which are delegated to it by the Brazilian government and the MME. ANEEL’s current responsibilities include, among others, (i) administering concessions for electric energy generation, transmission and distribution, including the approval of electricity tariffs, (ii) enacting regulations for the electric energy industry, (iii) implementing and regulating the exploitation of energy sources, including the use of hydroelectric power, (iv) promoting the public bidding process for new concessions, (v) settling administrative disputes among electricity generation entities and electricity purchasers and (vi) defining the criteria and methodology for the determination of the transmission tariffs.

National Electrical System Operator — ONS

The National Electrical System Operator (Operador Nacional do Sistema Elétrico), or ONS, is a non-profit organization that coordinates and controls electric utilities engaged in the generation, transmission and distribution of electric energy, in addition to other private participants such as importers, exporters, and free consumers. The primary role of the ONS is to oversee the generation and transmission operations in the Interconnected Power System, or SIN, subject to the ANEEL’s regulation and supervision. The objectives and principal responsibilities of the ONS include: operational planning for the generation industry, organizing the use of the domestic Interconnected Power System and international interconnections, guaranteeing that all parties in the industry have access to the transmission network in a non-discriminatory manner, assisting in the expansion of the electric energy system, proposing plans to the MME for extensions of the Basic Grid, and submitting rules for the operation of the transmission system for ANEEL’s approval.

Electric Energy Trading Chamber — CCEE

The Electric Energy Trading Chamber (Câmara de Comercialização de Energia Elétrica), or CCEE, is a non-profit organization subject to authorization, inspection and regulation by ANEEL. The CCEE replaced the Wholesale Energy Market, or MAE.

The CCEE is responsible, among other things, for (1) registering all the energy purchase agreements in the Regulated Market (Contratos de Comercialização de Energia no Ambiente Regulado), or CCEAR, and registering the agreements resulting from market adjustments and the volume of electricity contracted in the Free Market, and (2) the accounting for and clearing of short-term transactions. The CCEE is comprised of holders of concessions and permissions, authorized entities of the electricity industry, free and special consumers and its board of directors is comprised of four members appointed by these agents and one by the MME, which is the chairman of the board of directors.

Energy Research Company — EPE

On August 16, 2004 the Brazilian government created the Energy Research Company (Empresa de Pesquisa Energética), or EPE, a state-owned company, which is responsible for conducting strategic research on the energy industry, including with respect to electric energy, oil, gas, coal and renewable energy sources. The research carried out by EPE is used by MME in its policymaking role in the energy industry.

Energy Industry Monitoring Committee — CMSE

The New Industry Model Law created the Energy Industry Monitoring Committee (Comitê de Monitoramento do Setor Elétrico), or CMSE, which acts under the direction of the MME. The CMSE is responsible for monitoring the supply conditions of the system and for indicating the steps to be taken to correct existing problems.

Concessions

The Brazilian constitution provides that the development, use and sale of electric energy may be undertaken directly by the Brazilian government or indirectly through the granting of concessions, permissions or authorizations.

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Historically, the Brazilian electric energy industry has been dominated by generation, transmission and distribution concessionaires controlled by the Federal or State governments.

The companies or consortia that wish to build or operate facilities for generation, transmission or distribution of electricity in Brazil must apply to the MME or to the ANEEL, as representatives of the Brazilian government, for a concession, permission or authorization, as the case may be. Concessions grant rights to generate, transmit or distribute electricity in the relevant concession area for a specified period, as opposed to permissions and authorizations, which may be revoked at any time at the discretion of MME, in consultation with ANEEL. This period is usually 35 years for new generation concessions, and 30 years for new transmission or distribution concessions. An existing concession may be renewed at the granting authority’s discretion.

The Concession Law establishes, among other things, the conditions that the concessionaire must comply with when providing electricity services, the rights of the consumers, and the obligations of the concessionaire and the granting authority. Furthermore, the concessionaire must comply with regulations governing the electricity sector. The main provisions of the Concession Law are summarized below:

Adequate service. The concessionaire must render adequate service equally with respect to regularity, continuity, efficiency, safety and accessibility.

Use of land. The concessionaire may use public land or request the granting authority to expropriate necessary private land for the benefit of the concessionaire. In such case, the concessionaire shall compensate the affected private landowners.

Strict liability. The concessionaire is strictly liable for all damages arising from the provision of its services.

Changes in controlling interest. The granting authority must approve any direct or indirect change in the concessionaire’s controlling interest.

Intervention by the granting authority. The granting authority may intervene in the concession, by means of a presidential decree, to ensure the adequate performance of services, as well as the full compliance with applicable contractual and regulatory provisions. Within 30 days after the decree date, the granting authority’s representative is required to commence an administrative proceeding in which the concessionaire is entitled to contest the intervention. During the term of the administrative proceeding, a person appointed pursuant to the granting authority’s decree becomes responsible for carrying on the concession. If the administrative proceeding is not completed within 180 days after the decree date, the intervention ceases and the concession is returned to the concessionaire. The concession is also returned to the concessionaire if the granting authority’s representative decides not to terminate the concession and the concession term has not yet expired.

Termination of the concession. The termination of the concession agreement may be accelerated by means of expropriation and/or forfeiture. Expropriation is the early termination of a concession for reasons related to the public interest that must be expressly declared by law. Forfeiture must be declared by the granting authority after ANEEL or MME has made a final administrative ruling that the concessionaire, among other things, (1) has failed to render adequate service or to comply with applicable law or regulation, (2) no longer has the technical, financial or economic capacity to provide adequate service, or (3) has not complied with penalties assessed by the granting authority. The concessionaire may contest any expropriation or forfeiture in the courts. The concessionaire is entitled to indemnification for its investments in expropriated assets that have not been fully amortized or depreciated, after deduction of any amounts for fines and damages due by the concessionaire.

Expiration. When the concession expires, all assets, rights and privileges that are materially related to the rendering of the electricity services revert to the Brazilian government. Following the expiration, the concessionaire is entitled to indemnification for its investments in assets that have not been fully amortized or depreciated as of the expiration.

Penalties. ANEEL’s regulation governs the imposition of sanctions against the participants in the electricity sector and classifies the appropriate penalties based on the nature and importance of the breach (including warnings, fines and forfeiture). For each breach, the fines can be up to two per cent of the revenue (net of value-added tax and services tax) of the concessionaire in the 12-month period preceding any assessment notice. Some infractions that may result in fines relate to the failure of the agent to request ANEEL’s approval including the following: (1) execution of contracts between related parties in the cases provided by regulation; (2) sale or assignment of the assets related to services rendered as well as the imposition of any encumbrance (including any security, bond, guarantee, pledge and mortgage) on them or any other assets related to the concession or the revenues of the electricity services; and (3) changes in controlling interest of the holder of the authorization or concession. In case of contracts executed between related parties that are submitted for ANEEL’s approval, ANEEL may seek to impose restrictions on the terms and conditions of these contracts and, in extreme circumstances, determine that the contract be rescinded.

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The New Industry Model Law

Since 1995, the Federal Government has taken a number of measures to reform the Brazilian electric energy industry. These culminated, on March 15, 2004, in the enactment of the New Industry Model Law, which further restructured the power industry with the ultimate goal of providing consumers with a secure electricity supply at an adequate tariff. The New Industry Model Law was implemented by Decree No. 5,163, enacted on July 30, 2004.

The New Industry Model Law introduced material changes to the regulation of the power industry, with a view to (i) providing incentives to private and public entities to build and maintain generation capacity and (ii) assuring the supply of electricity within Brazil at adequate tariffs through competitive electricity public bidding processes. The key features of the New Industry Model Law include:

• Creation of a parallel environment for the trading of electricity, including: (1) the regulated market, a more stable market in terms of supply of electricity; and (2) a market specifically addressed to certain participants (i.e., free consumers and commercialization companies), called the free market, that permits a certain degree of competition.

• Restrictions on certain activities of distributors, so as to require them to focus on their core business of distribution, to promote more efficient and reliable services to captive consumers.

• Elimination of self-dealing, in order to provide an incentive to distributors to purchase electricity at the lowest available prices rather then buying electricity from related parties.

• Respect for contracts executed prior to the New Industry Model Law, in order to provide regulatory stability for transactions carried out before its enactment.

The New Industry Model Law excludes Eletrobrás and its subsidiaries from the National Privatization Program, which is a program originally created by the Brazilian government in 1990 to promote the privatization process of state-owned companies.

Regulations under the New Industry Model Law include, among other items, rules relating to auction procedures, the form of power purchase agreements and the method of passing costs through to final consumers, among other things.

Under these regulations, all electricity-purchasing agents must contract all of their electricity demand under the guidelines of the new model. Electricity-selling agents must provide evidentiary support linking the allotted energy to be sold to existing or planned power generation facilities. Agents that do not comply with such requirements are subject to penalties imposed by ANEEL.

Beginning in 2005, all electricity generation, distribution and trading companies, independent power producers and free and special consumers are required to notify MME, by August 1 of each year, of their estimated electricity demand or estimated electricity generation, as the case may be, for each of the subsequent five years. Each distribution company will be required to notify MME, within the 60-day period preceding each electricity auction, of the amounts of electricity that it intends to contract in the auction. Based on this information, the MME must establish the total amount of energy to be contracted in the Regulated Market and the list of generation projects that will be allowed to participate in the auctions. Distribution companies will also be required to specify the portion of the contracted amount they intend to use to supply potentially free consumers.

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Parallel Environment for the Trading of Electric Energy

Under the New Industry Model Law, electricity purchase and sale transactions are carried out in two different segments: (1) the regulated market, which contemplates the purchase by distribution companies through public auctions of all electricity necessary to supply their customers and (2) the free market, which contemplates purchase of electricity by non-regulated entities (such as free consumers and energy traders).

Electricity distribution companies fulfill their electricity supply obligations primarily through public auctions. In addition to these auctions, distribution companies will be able to purchase electricity outside the public bidding process from: (1) generation companies that are connected directly to such distribution company, except for hydro generation companies with capacity higher than 30 MW and certain thermo generation companies, (2) electricity generation projects participating in the initial phase of the Proinfa Program, a program designed to diversify Brazil’s energy sources, and (3) the Itaipu power plant. The electricity generated by Itaipu continues to be sold by Eletrobrás to the distribution concessionaires operating in the South/Southeast/Center-Western Interconnected Power System, although no specific contract was entered into by such concessionaires. The rates at which the Itaipu-generated electricity is traded are denominated in U.S. dollars and established pursuant to a treaty between Brazil and Paraguay. As a consequence, Itaipu rates rise or fall in accordance with the variation of the U.S. dollar/real exchange rate. Changes in the price of Itaipu-generated electricity are, however, subject to the Parcel A cost recovery mechanism discussed below under “ — Distribution Tariffs.”

The Regulated Market

In the regulated market, distribution companies purchase their expected electricity requirements for their captive customers from generators through public auctions. The auctions are administered by ANEEL, either directly or indirectly through the CCEE.

Electricity purchases are made through two types of bilateral agreements: Energy Agreements (Contratos de Quantidade de Energia) and (2) Capacity Agreements (Contratos de Disponibilidade de Energia). Under an Energy Agreement, a generator commits to supply a certain amount of electricity and assumes the risk that its electricity supply could be adversely affected by hydrological conditions and low reservoir levels, among other conditions, which could interrupt the supply of electricity. In such a case, the generator would be required to purchase the electricity elsewhere in order to comply with its supply commitments. Under a Capacity Agreement, a generator commits to make a certain amount of capacity available to the Regulated Market. In such a case, the generator’s revenue is guaranteed and the distributors must bear the risk of a supply shortage. Together, these agreements comprise the energy purchase agreements in the Regulated Market, Contratos de Comercialização de Energia no Ambiente Regulado - CCEAR.

According to the New Industry Model Law, electricity distribution entities will be entitled to pass through to their respective customers all costs related to electricity they purchased through public auction as well as any taxes and industry charges.

With respect to the granting of new concessions, the newly enacted regulations require bids for new hydroelectric generation facilities to include, among other things, the minimum percentage of electricity to be supplied to the Regulated Market.

The Free Market

The free market covers transactions between generation concessionaires, Independent Power Producers, or IPPs, self-generators, energy traders, importers of electric energy, free consumers and the consumers called “special consumers”. IPPs are generation entities that sell the totality or part of their electricity to free consumers, distribution concessionaires and trading agents, among others. The free market will also include existing bilateral contracts between generators and distributors until they expire. Upon expiration, such contracts must be executed under the New Industry Model Law guidelines.

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A consumer that is eligible to choose its supplier (potentially free consumer) may only be able to rescind its contract with the local distributor and become a free consumer by notifying such distributor at least 15 days before the date such distributor is required to state its estimated electricity needs for the next auction. Further, such consumer may only begin acquiring electricity from another supplier in the year following the one in which the local distributor was notified. Once a potentially free consumer has opted for the free market, it may only return to the regulated system once it has given the distributor of its region a five-year notice, provided that the distributor may reduce such term at its discretion. Such an extended period of notice seeks to assure that, if necessary, the distributor could buy the additional energy in the Regulated Market without imposing extra costs to the captive market.

In addition to free consumers, certain consumers with capacity equal to or greater than 500 kW may choose to purchase energy in the free market, subject to certain terms and conditions. These consumers are called “special consumers”. Special Consumers may only purchase energy from (i) small hydroelectric generators with capacity between 1,000 kW and 30,000 kW, (ii) generators with capacity limited to 1,000 kW, and (iii) alternative energy generators (solar, wind and biomass enterprises) with capacity injected in the system not greater than 30,000 kW. A Special Consumer may terminate its contract with the local distributor with 180 days prior notice for contracts with indefinite terms. For contracts with a definite term, the consumer must fulfill the contract or for long-term contracts, the consumer may terminate its contract with 36 months notice. The Special Consumer may return to the regulated system upon 180 days prior notice.

State-owned generators may sell electricity to free consumers; however, as opposed to private generators, they are obligated to do so through an auction process.

Auctions on the Regulated Market

Electricity auctions for new generation projects in process are held (1) five years before the initial delivery date (referred to as “A-5’’ auctions) and (2) three years before the initial delivery date (referred to as “A-3’’ auctions). Electricity auctions from existing power generation facilities take place (1) one year before the initial delivery date (referred to as “A-1’’ auctions) and (2) approximately four months before the delivery date (referred to as “market adjustments’’). The invitations to bid in the auctions are prepared by ANEEL, in compliance with guidelines established by the MME, including the requirement to use the lowest bid as the criterion to determine the winner of the auction.

Each generation company that participates in an auction executes a contract for purchase and sale of electricity with each distribution company, in proportion to the distribution companies’ respective estimated demand for electricity. The only exception to these rules relates to the market adjustment auction, where the contracts are between specific selling and distribution companies. The CCEAR of both “A-5’’ and “A-3’’ auctions have a term of between 15 and 30 years, and the CCEAR of “A-1’’ auctions have a term between five and 15 years. Contracts arising from market adjustment auctions are limited to a two-year term.

With respect to the CCEAR related to electricity generated by existing generation facilities, there are three alternatives for the permanent reduction of contracted electricity: (1) compensation for the exit of potentially free consumers from the Regulated Market, (2) reduction, at the distribution companies’ discretion, of up to 4% per year of the annual contracted amount due to market deviations from the estimated market projections, beginning two years after the initial electricity demand was declared and (3) adjustments to the amount of electricity established in the energy acquisition contracts entered into before March 17, 2004.

Since 2004, CCEE has conducted five auctions for new generation projects, six auctions for existing power generation facilities and one auction for alternate generation projects. No later than August 1^st of each year, the generators and distributors provide their estimated electricity generation or estimated electricity demand for the 5 subsequent years. Based on this information, MME establishes the total amount of electricity to be traded in the auction and sets the generation companies that would participate in the auction. The auction is carried out in two phases via an electronic system. As a general rule, the contracts to be executed in the context of the auction have the following terms (i) from 15 to 30 years as of the supply start-up in case of new generation projects, (ii) from 5 to 15 years as of the auction’s subsequent year in case of existing power generation facilities and (iii) from 10 to 30 years as of the supply start-up in case of alternate generation projects.

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After the completion of the auction, generators and distributors execute the CCEAR, in which the parties establishe the price and amount of the energy contracted in the auction. The CCEAR sets forth that the price will be annually adjusted upon the variation of the IPCA (Índice Nacional de Preços ao Consumidor Amplo, calculated and published by Fundação Instituto Brasileiro de Geografia e Estatística – IBGE). The distributors grant financial guaranties to the generators (mainly receivables from the distribution service) to secure their payment obligations under the CCEAR.

The Annual Reference Value

The regulation also establishes a mechanism, the Annual Reference Value, which limits the amounts of costs that can be passed through to final consumers. The Annual Reference Value corresponds to the weighted average of electricity prices in the “A-5’’ and “A-3’’ auctions, calculated for all distribution companies.

The Annual Reference Value creates an incentive for distribution companies to contract for their expected electricity demands at the lowest price in the “A-5’’ auctions and the “A-3’’ auctions. Distributors that buy electricity at a price lower than the Annual Reference Value in these auctions are allowed to pass through the full amount of the Annual Reference Value to consumers for three years. The Annual Reference Value is also applied in the first three years of the power purchase agreements from new power generation projects. After the fourth year, the electricity acquisition costs from these projects are allowed to be fully passed through. The regulation establishes the following limitations on the ability of distribution companies to pass through costs to consumers: (1) No pass-through of costs for electricity purchases that exceed 103% of actual demand; (2) Limited pass-through of costs for electricity purchases made in an “A-3’’ auction, if the volume of the acquired electricity exceeds 2% of the demand for electricity purchased in the “A-5’’ auctions; (3) Limited pass-through of electricity acquisition costs from new electricity generation projects if the volume contracted under the new contracts related to existing generation facilities is lower than 96% of the volume of electricity provided for in the expiring contract; (4) From 2005-2008, electricity purchases from existing facilities in the “A-1’’ auction is limited to 1% of requirements. If the acquired electricity in the “A-1’’ auction exceeds 1%, pass-through of costs to final consumers is limited to 70% of the average value of such acquisition costs of electricity generated by existing generation facilities for delivery between 2005 and 2008. The MME establishes the maximum acquisition price for electricity generated by existing projects that take part in the auctions for sale of electricity to distributors; and, if distributors do not comply with the obligation to fully contract their demand, the pass-through of the costs from energy acquired in the short-term market will be the lower of the spot price (Preço de Liquidação de Diferenças or PLD) and the Annual Reference Value.

Electric Energy Trading Convention

ANEEL Resolutions No. 109, of 2004 and No. 210, of 2006, govern the Electric Energy Trading Convention (Convenção de Comercialização de Energia Elétrica). This convention regulates the organization and administration of the CCEE as well as the conditions for trading electric energy. It also defines, among other things, (1) the rights and obligations of CCEE participants, (2) the penalties to be imposed on defaulting participants, (3) the structure for dispute resolution, (4) the trading rules in both regulated and free markets and (5) the accounting and clearing process for short-term transactions.

Restricted Activities of Distributors

Distributors in the Interconnected Power System are not permitted to (i) conduct businesses related to the generation or transmission of electric energy, (ii) sell electric energy to free consumers, except for those in their concession area and under the same conditions and tariffs maintained with respect to captive consumers, (iii) hold, directly or indirectly, any interest in any other company, corporation or partnership or (iv) conduct businesses that are unrelated to their respective concessions, except for those permitted by law or in the relevant concession agreement. Generators will not be allowed to hold equity interests in excess of 10% in distributors.

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Elimination of Self-Dealing

Since the purchase of electricity for captive customers is now performed through the Pool, “self-dealing” (under which distributors were permitted to meet up to 30% of their electric energy needs through energy that was either self-produced or acquired from affiliated companies) is no longer permitted, except in the context of agreements that were approved by ANEEL before the enactment of the New Industry Model Law.

Challenges to the Constitutionality of the New Industry Model Law

Political parties are currently challenging the New Industry Model Law on constitutional grounds before the Brazilian Supreme Court. In October 2007, a decision of the Brazilian Supreme Court on injunctions presented on the matter was published, denying the injunctions by majority of votes. To date, the Brazilian Supreme Court has not reached a final decision, and we do not know when such a decision may be reached. While the Brazilian Supreme Court is reviewing the law, its provisions are in effect. Regardless of the Supreme Court’s final decision, certain portions of the New Industry Model Law relating to restrictions on distributors engaging in businesses unrelated to the distribution of electricity, including sales of energy by distributors to free consumers and the elimination of self-dealing are expected to remain in full force and effect.

If all or a relevant portion of the New Industry Model Law is deemed unconstitutional by the Brazilian Supreme Court, the regulatory scheme introduced by the New Industry Model Law may not come into effect, which will create uncertainty as to how and when the Brazilian government will be able to reform the electric energy sector.

Ownership Limitations

ANEEL had established limits on the concentration of certain services and activities within the electric energy industry, which it recently eliminated. A new regulation from ANEEL addressing these limitations was released for public consideration.

Tariffs for the Use of the Distribution and Transmission Systems

ANEEL oversees tariff regulations that govern access to the distribution and transmission systems and establish tariffs for these systems. The tariffs are (i) network usage charges, which are charges for the use of the proprietary local grid of distribution companies (“TUSD”) and (ii) tariffs for the use of the transmission system, which is the Basic Grid and its ancillary facilities (“TUST”).

TUSD

The TUSD is paid by generators and free and special consumers for the use of the distribution system of the distribution concessionaire to which the relevant generator or free or special consumer is connected. The amount to be paid by the agent connected to the distribution system is calculated by multiplying the amount of electricity contracted with the distribution concessionaire for each connection point, in kW, by the tariff in R$/kW which is set by ANEEL. The TUSD has two components: (1) the remuneration of the concessionaire for the use of the proprietary local grid, known as TUSD Service, which varies in accordance with each customer’s energy peak load, and (2) the regulatory charges applicable to the use of the local grid, known as TUSD Charges, which are set by regulatory authorities and linked to the quantity of energy consumed by each customer.

TUST

The TUST is paid by distribution companies, generators and free and special consumers for the use of the Basic Grid and is revised annually according to (i) an inflation index and (ii) the annual revenue of the transmission companies, as determined by ANEEL. According to criteria established by ANEEL, owners of the different parts of the transmission grid were required to transfer the coordination of their facilities to the ONS in return for receiving regulated payments from the transmission system users. Network users, including generation companies, distribution companies and free and special Consumers, have signed contracts with the ONS entitling them to the use of the transmission grid in return for the payment of certain tariffs. Other parts of the grid that are owned by transmission companies but which are not considered part of the Basic Grid are made directly available to the interested users for a specified fee.

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Distribution Tariffs

Distribution tariff rates (including the TUSD) are subject to review by ANEEL, which has the authority to adjust and review these tariffs in response to changes in energy purchase costs and market conditions. When adjusting distribution tariffs, ANEEL divides the costs of distribution companies between (i) costs that are beyond the control of the distributor, or Parcel A costs, and (ii) costs that are under control of distributors, or Parcel B costs. The readjustment of tariffs is based on a formula that takes into account the division of costs between the two categories.

Parcel A costs include, among others, the following factors:

• costs of electricity purchased from Itaipu;

• costs of electricity purchased pursuant to bilateral agreements that are freely negotiated between the parties;

• costs of electricity purchased pursuant to CCEARs;

• certain other charges for connection to the transmission and distribution systems;

• the cost of regulatory charges; and

• the costs associated with research and development and energy efficient consumption.

Parcel B costs are determined by subtracting all of the Parcel A costs from the distribution company’s revenues, excluding ICMS, a state tax levied on sales.

Each distribution company’s concession agreement provides for an annual readjustment (reajuste anual). In general, Parcel A costs are fully passed through to consumers. Parcel B costs, however, are restated for inflation in accordance with the IGP-M index.

Electricity distribution concessionaires are also entitled to periodic revisions every four or five years. These revisions are aimed at (1) assuring necessary revenues to cover efficient Parcel B operational costs and adequate compensation for investments deemed essential for the services within the scope of each such company’s concession and (2) determining the “X factor,” which is based on three components: (a) expected gains of productivity from increase in scale, (b) evaluations by consumers (verified by ANEEL) and (c) labor costs. The X factor is used to adjust the proportion of the change in the IGP-M index that is used in the annual adjustments. Accordingly, upon the completion of each periodic revision, application of the X factor requires distribution companies to share their productivity gains with final consumers.

In addition, electricity distribution concessionaires are entitled to an extraordinary tariff review (revisão extraordinária) on a case-by-case basis, to ensure their financial stability and compensate them for unpredictable costs, including taxes, that significantly change their cost structure.

With the introduction of the New Industry Model Law, the MME has acknowledged that the variable costs associated with the purchase of electric energy may be included by means of the Parcel A Account or CVA, an account created to recognize some of our costs when ANEEL adjusts the tariffs of our distribution subsidiaries. See “Item 5—Operating and Financial Review and Prospects—Overview—Recoverable Costs Variations—Parcel A Costs.”

In October 2006, ANEEL established the methodology and procedures applicable to the periodic revisions for 2007 through 2010 for distribution concessionaires, based on the practices developed during a previous round of the periodic tariff reviews. Currently, new regulation from ANEEL aiming at improving the revision process is under public consideration.

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Government Incentives to the Energy Sector

In 2000, a Federal decree created the Thermoelectric Priority Program (Programa Prioritário de Termeletricidade, or PPT) for purposes of diversifying the Brazilian energy matrix and decreasing its strong dependency on hydroelectric plants. The incentives granted to the thermoelectric plants included in the PPT are: (i) guaranty of gas supply for twenty years, according to regulation from the MME, (ii) assurance of the costs related to the acquisition of the electric energy produced by thermoelectric plants will be transferred to tariffs up to the normative value established by ANEEL and (iii) guaranty of access to a BNDES special financing program for the electric energy industry.

In 2002, the Federal Government established the Proinfa Program. Under the Proinfa Program, Eletrobrás shall purchase the energy generated by alternative energy sources for a period of up to twenty years, and this energy is to be acquired by distribution companies for delivery to final customers. In its initial phase, the Proinfa Program is limited to a total contracted capacity of 3,300 MW. The objective of this initiative is to reach a contracted capacity of up to 10% of the total annual consumption of electricity in Brazil within up to 20 years. The energy production for the commercialization in the Program will not be made by generation concessionaires, like us, nor by IPPs. On the other hand, such production may only be made by an autonomous independent producer, which may not be controlled by or affiliated with a generation concessionaire or an IPP, or affiliated with their controlling entities.

In order to create incentives for alternative generators, the Federal Government established a reduction not inferior than 50% in the TUSD amount owed by (i) small hydroelectric generators with capacity between 1,000 kW and 30,000 kW, (ii) generators with capacity equal to 1,000 kW and (iii) alternative energy generators (solar, eolic and biomass generators) with capacity equal to 30,000 kW. The reduction is applicable to the TUSD due by the generation source and also by its consumer. The amount of the TUSD reduction will be include like “financial components” in the tariff readjustment or tariff revision.

Regulatory Charges

RGR Fund and UBP

In certain circumstances, electric energy companies are compensated for certain assets used in connection with a concession if the concession is revoked or is not renewed. In 1971, the Brazilian congress created a reserve fund designed to provide funds for such compensation (“RGR Fund”). In February 1999, ANEEL revised the assessment of a fee requiring public-industry electric companies to make monthly contributions to the RGR Fund at an annual rate equal to 2.5% of the company’s fixed assets in service, not to exceed 3% of total operating revenues in any year. In recent years, no concessions have been revoked or have failed to be renewed, and the RGR has been used principally to finance generation and distribution projects. The RGR is scheduled to be phased out by 2010 and ANEEL shall revise the applicable tariffs so such that the consumer will receive some benefit from the termination of the RGR.

The Federal Government has imposed a fee on IPPs similar to the fee levied on public-industry generation companies in connection with the RGR. IPPs are required to make contributions for using a public asset (Uso de Bem Público, or UBP) according to the rules of the corresponding public bidding process for the granting of concessions. Eletrobrás received the UBP payments until December 31, 2002. All payments related to the UBP since December 31, 2002 are paid directly to the Federal Government.

CCC

Distribution companies (and also some transmission companies responsible for free consumers) must contribute to the Conta de Consumo de Combustível (“CCC Account”). The CCC Account was created in 1973 to generate financial reserves to cover fossil fuel costs in thermoelectric power plants in the event of a rainfall shortage which would require increased use of thermal plants. The CCC currently subsidizes the distribution systems in isolated areas where the distribution costs are higher than in the Interconnected Power System. The annual CCC Account contributions are calculated on the basis of estimates of the cost of fuel needed by the thermoelectric power plants in the succeeding year. The CCC Account is administered by Eletrobrás. The CCC Account, in turn, reimburses electric companies for a substantial portion of the fuel costs of their thermoelectric power plants.

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On February 1998, the Federal Government provided for the phasing out of the CCC Account. During the 2003-2006 period, subsidies from the CCC Account were phased out for thermal power plants constructed prior to February 1998 and belonging to the Interconnected Power System. Thermal power plants constructed after that date were not entitled to subsidies from the CCC Account. In April 2002, the Federal Government established that subsidies from the CCC Account would continue to be paid, for a period of 20 years, to those thermoelectric plants located in isolated systems.

CDE

In 2002, the Federal Government instituted the Electric Energy Development Account, Conta de Desenvolvimento Energético (“CDE Account”), which is funded through annual payments made by concessionaires for the use of public assets, penalties and fines imposed by ANEEL and the annual fees paid by agents offering electric energy to final consumers, by means of a charge to be added to the tariffs for the use of the transmission and distribution transmission systems. These fees are adjusted annually. The CDE Account was created to support (i) the development of energy production throughout Brazil, (ii) the production of energy by alternative energy sources and (iii) the universalization of electric energy services throughout Brazil. The CDE will be in effect for twenty-five years and shall be regulated by the executive branch and managed by Eletrobrás.

ESS

Resolution no. 173 of November 28, 2005 established a provision for the system service charge, Encargo de Serviço do Sistema (“ESS”), which since January 2006 has been included in price and fee readjustments for distribution concessionaires that are part of the National Interconnected Grid (Sistema Interligado Nacional). This charge is based on the annual estimates made by the National Electrical System Operator, Operador Nacional do Sistema Elétrico (“ONS”), on October 31 of each year.

Fee for the Use of Water Resources

The Power Industry Law requires that holders of a concession and authorization to use water resources must pay a fee of 6.75% of the value of the energy they generate by using such facilities. This charge must be paid to the federal district, states and municipalities where the plant or the plant’s reservoir is located.

ANEEL Inspection Fee (TFSEE)

The ANEEL Inspection Fee is an annual fee due by the holders of concessions, permissions or authorizations in the proportion of their dimension and activities. Currently, the ANEEL Inspection Fee is deducted from the RGR Fund.

Default on the Payment of Regulatory Charges

The New Industry Model Law provides that the failure to pay required contributions to the RGR Fund, Proinfa Program, CDE Account, CCC Account, or certain payments, such as those due from the purchase of electric energy in the regulated market or from Itaipu will prevent the defaulting party from receiving readjustments or reviews of their tariffs (expect for an extraordinary review) and will also prevent the defaulting party from receiving funds from the RGR Fund, CDE Account or CCC Account.

Energy Reallocation Mechanism

Centrally dispatched hydrogenerators are protected against certain hydrological risks by the Energy Reallocation Mechanism (“MRE”) which attempts to mitigate the risks involved in the generation of hydrological energy by mandating that hydrogenerators share the hydrological risks of the Interconnected Power System. Under Brazilian law, each hydroelectric plant is assigned an “Assured Energy”, which is determined in each relevant concession agreement, irrespective of the volume of electricity generated by the facility. The MRE transfers surplus electricity from those generators that have produced electricity in excess of their Assured Energy to those generators that have produced less than their Assured Energy. The effective generation dispatch is determined by ONS, which takes into account nationwide electricity demand and hydrological conditions. The volume of electricity actually generated by the plant, either less or in excess to the Assured Energy, is priced pursuant to a tariff denominated “Energy Optimization Tariff” which covers the operation and maintenance costs of the plant. This revenue or additional expense will be accounted monthly by each generator.

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ITEM 4A. UNRESOLVED STAFF COMMENTS

None.

ITEM 5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS

The following discussion should be read in conjunction with our audited consolidated financial statements and the notes thereto included elsewhere in this annual report. Our financial statements have been prepared in accordance with Brazilian Accounting Principles, which differ in certain respects from U.S. GAAP. Note 35 to our audited consolidated financial statements provides a description of the principal differences between Brazilian Accounting Principles and U.S. GAAP, as they relate to us, and a reconciliation to U.S. GAAP of net income and shareholders’ equity. See “Presentation of Financial Information.”

Overview

We have eight distribution subsidiaries. All are fully consolidated, but prior to June 2006, we owned 67.07% of RGE and accounted for it using proportionate consolidation. We acquired CPFL Santa Cruz in December 2006, and it is included in our income statement beginning in January 2007. We acquired CPFL Jaguariúna and its subsidiaries in June 2007, and they are included in our income statement beginning in July 2007.

We account for four of our generation subsidiaries (CERAN, BAESA, ENERCAN and Foz do Chapecó) using proportionate consolidation. Those entities own a total of six generation facilities, three of which are currently under construction—Castro Alves and 14 de Julho (both part of CERAN) and Foz do Chapecó. ENERCAN became fully operational in May 2007.

We are a holding company and, through subsidiaries, we (a) distribute electricity to customers in our concession areas, (b) generate electricity and develop generation projects and (c) engage in electricity commercialization and the provision of electricity-related services. The most important drivers of our financial performance are the operating income margin and cash flows from our regulated distribution business. In recent years, this business has produced reasonably stable margins, and its cash flows, while sometimes subject to short-term variability, have been stable over the medium term.

In addition to achieving the best returns we can from our regulated distribution business, we have three broad initiatives to improve our future financial performance—the growth in our generating capacity, the acquisition of additional distributors and the development of our commercialization and electricity-related services business. We have a portfolio of hydroelectric generation projects, which are becoming operational. Of this new generation capacity, approximately 157 MW became operational in 2006, approximately 429 MW became operational in 2007 and approximately 149 MW are expected to become operational by the end of 2008. We expect a further 436 MW of new generation capacity will be operational by the end of 2010. We plan to use the additional electricity generated by these projects to supply electricity to our distribution business, and we currently expect that this degree of integration will improve our consolidated profit margin and our cash flows. In 2006, we acquired 32.69% of RGE and 99.99% of CPFL Santa Cruz. In 2007, CPFL Energia acquired the assets of CMS Energy Brasil (currently CPFL Jaguariúna S.A.), which were comprised of four distributors, two companies engaged in the energy commercialization business and generation assets (consisting of 9 Small Hydroelectric Plants and an interest in UHE Luiz Eduardo Magalhães), which total 87 MW.

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There are factors beyond our control that can have a significant impact, positive or adverse, on our financial performance, as we have seen in recent years with the effects of an energy crisis in 2001, increases in interest rates and indexation rates on our debt in 2002, and important regulatory changes that occurred in 2004 and 2005. We also face periodic changes in our rate structure, resulting from the periodic revision of our rates, and the current cycle of periodic revisions, which is taking effect during 2007 and 2008 at each of our distribution companies, will result in reduced rates. We expect the reduced rates to adversely affect our revenues, operating income and net income in 2008, but the magnitude of this impact will depend on our success in improving our margins through cost control, increased generation capacity, increased volume sold by our distribution subsidiaries and growth in the commercialization business.

Background

Regulated Distribution Tariffs

Our results of operations are significantly affected by changes in regulated tariffs for electricity. In particular, most of our revenues are derived from sales of electricity to captive final customers at regulated tariffs. In 2007, sales to captive consumers represented 71.1% of the volume of electricity we delivered and 85.8% of our operating revenues, compared to 69.8% and 86.2%, respectively, in 2006. These proportions may decline if customers migrate from captive to free status.

Our operating revenues and our margins depend substantially on the tariff-setting process, and our management focuses on maintaining a constructive relationship with ANEEL, the Brazilian government and other market participants so that the tariff-setting process fairly reflects our interests and those of our customers and shareholders. For a description of tariff regulations, see “Item 4. Information on the Company— The Brazilian Power Industry—Distribution Tariffs” and “Item 4. Information on the Company—Customers, Analysis of Demand and Tariffs.”

Tariffs are determined separately for each of our eight distribution subsidiaries as follows:

• Our concession agreements provide for an annual adjustment (reajuste anual) to take account of changes in our costs, which for this purpose are divided into costs that are beyond our control (known as Parcel A costs) and costs that we can control (known as Parcel B costs). Parcel A costs include, among other things, increased prices under long-term supply contracts, and Parcel B costs include, among others, the return on investment related to our concessions and their expansion, as well as maintenance and operational costs. Our ability to fully pass through to final consumers our electricity acquisition costs is subject to: (a) our ability to accurately forecast our energy needs and (b) a ceiling linked to a reference value, the Annual Reference Value. The Annual Reference Value is the weighted average of electricity acquisition costs resulting from electricity prices of all public auctions carried out by ANEEL and CCEE in the regulated market for electricity to be delivered five and three years from any such auction and only applies during the first three years following the commencement of delivery of the acquired electricity. See “The Brazilian Power Industry — The New Industry Model Law” for a more detailed description of all the limitations on the ability of distribution companies to fully pass through their electricity acquisition costs to final consumers. Under agreements that were in force before the enactment of these regulatory reforms, we pass through the costs of acquired electricity subject to a ceiling determined by the Brazilian government. An annual adjustment of tariffs occurs every April for CPFL Paulista and RGE, every October for CPFL Piratininga and every February for CPFL Santa Cruz, CPFL Leste Paulista, CPFL Sul Paulista, CPFL Mococa and CPFL Jaguari. There is no annual adjustment in a year with a periodic revision.

• Our concession agreements provide for a periodic revision (revisão periódica), every five years for CPFL Paulista and RGE and every four years for CPFL Piratininga, CPFL Santa Cruz, CPFL Leste Paulista, CPFL Sul Paulista, CPFL Mococa and CPFL Jaguari, to restore the financial equilibrium of our tariffs as contemplated by the concession agreements and to determine a reduction factor (known as the X factor) in the amount of Parcel B cost increases passed on to our customers. For additional information, see “Item 4. Information on the Company— The Brazilian Power Industry—Distribution Tariffs.”

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• Brazilian law also provides for extraordinary revision (revisão extraordinária) to take account of unforeseen changes in our cost structure. In particular, we currently charge supplemental tariffs that were introduced as a result of the energy crisis in 2001-2002. See “The 2001-2002 Energy Crisis and Related Regulatory Measures” below.

Annual Adjustment

Tariff increases apply differently to different customer classes, with generally higher increases for customers using higher voltages, to reduce the effects of historical cross-subsidies in their favor that were mostly eliminated in 2007. The following table sets forth the average percentage increase in our tariffs resulting from each annual adjustment from 2005 through the date of this annual report. Rates of tariff increase should be evaluated in light of the rate of Brazilian inflation. See “— Background—Brazilian Economic Conditions.”

	2005						2006						2007
	Economic  Adjustment(1)		Regulatory  Adjustment (2)		Total Adjustment		Economic  Adjustment(1)		Regulatory  Adjustment (2)		Total  Adjustment		Economic  Adjustment(1)		Regulatory  Adjustment (2)		Total  Adjustment
CPFL Paulista(3)	10.58%		7.16%		17.74%		7.12%		3.70%		10.83%		2.60%		4.46%		7.06%
CPFL Piratininga(3)	0.74%		0.80%		1.54%		4.40%		6.39%		10.79%		-		-		(4)
RGE	14.57%		7.36%		21.93%		5.06%		5.13%		10.19%		3.77%		2.28%		6.05%
CPFL Santa Cruz	15.57%		4.13%		19.70%		3.74%		3.29%		7.03%		4.56%		1.15%		5.71%
CPFL Mococa	18.38%		0.12%		18.50%		5.56%		-0.04%		5.52%		6.70%		2.91%		9.61%
CPFL Leste Paulista	20.40%		-2.23%		18.17%		2.90%		4.72%		7.62%		3.52%		-0.21%		3.31%
CPFL Sul Paulista	15.19%		3.26%		18.45%		1.51%		4.58%		6.09%		1.64%		3.88%		5.52%
CPFL Jaguari	17.77%		-8.30%		9.47%		1.49%		4.19%		5.68%		-0.38%		2.04%		1.66%

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Periodic Revisions

The following table sets forth the percentage change in our tariffs resulting from the first and second cycles of periodic revisions. See Note 3(b.2) and Note 34 to our audited consolidated financial statements for related tariff adjustments. The rate reductions under the second cycle are taking effect at each of our distribution subsidiaries between October 2007 and April 2008, and we expect that they will adversely affect our revenues, operating income and net income in 2008.

		First Cycle				Second Cycle(1)
				Total				Economic		Regulatory		Total
		Adjustment Date		Adjustment		Adjustment Date		Adjustment		Adjustment		Adjustment
CPFL Paulista		April, 8 2003		20.66%		April 8, 2008		-13.69%		0.08%		-13.61%
CPFL Piratininga		October 23, 2003		10.14%		October 23, 2007		-10.94%		0.83%		-10.11%
RGE		April 19, 2003		27.96%		April 19, 2008		-5.37%		10.15%		4.77%
CPFL Santa Cruz		February 3, 2004		17.14%		February 3, 2008		-9.73%		2.60%		-7.13%
CPFL Mococa		February 3, 2004		21.73%		February 3, 2008		-8.40%		2.75%		-5.65%
CPFL Leste Paulista		February 3, 2004		20.10%		February 3, 2008		-2.69%		1.04%		-1.65%
CPFL Sul Paulista		February 3, 2004		12.29%		February 3, 2008		-2.98%		-0.59%		-3.57%
CPFL Jaguari		February 3, 2004		-6.17%		February 3, 2008		-0.35%		-1.23%		-1.58%

Sales to Potentially Free Consumers

The Brazilian government has introduced regulatory changes intended to foster the growth of open-market energy transactions by permitting qualifying consumers to opt out of the system of tariff regulation and become “free” consumers entitled to contract freely for electricity. See “The Brazilian Power Industry—The Free Market.” To date, as compared to the total number of our captive customers, the number of potentially free consumers is relatively small, but they account for a significant amount of our electricity sales and revenues. In 2007, approximately 22.9% of our electricity sales was to supply potentially free consumers. Most of our potentially free consumers have not elected to become free consumers. We believe this is because (1) they consider that the advantages of negotiating for a long-term contract at lower rates than the regulated tariff are outweighed by the need to bear additional costs (particularly transmission costs) and the long-term price risk and (2) some of our potentially free consumers, who entered into contracts before July 1995, are limited to changing to suppliers that purchase from renewable energy sources, such as Small Hydroelectric Power Plants or biomass. Even if a consumer decides to migrate from the regulated tariff system and becomes a free consumer, it still would have to pay us network usage charges, and such payments would mitigate the loss in operating income from any such migration. We do not expect to see a substantial number of our customers become free consumers, but the prospects for migration between the different markets (captive and free) over the long term, and its implications for our financial results, are difficult to predict.

Prices for Purchased Electricity

We purchase the majority of our electricity from large Brazilian generation companies under long-term contracts whose prices are regulated by ANEEL. The prices of electricity purchased by our distribution companies under contracts executed in the regulated market are regulated by ANEEL, while the prices of electricity purchased in the free market are based on prevailing market rates, according to bilateral settlement. In 2007, we purchased 48,162 GWh, compared to 45,998 GWh in 2006. The prices under the long-term contracts are adjusted annually to reflect increases in certain generation costs and inflation. Most of our contracts have adjustments linked to the annual adjustment in distribution tariffs, so that the increased costs are passed through to our customers in increased tariffs. As an increasing proportion of our energy is purchased at the public auctions, the success of our strategies in these auctions affects our margins and our exposure to price and market risk, since our ability to pass through costs of electricity purchases will be linked to the successful projection of our expected demand.

We also purchase a substantial amount of electricity from Itaipu under take-or-pay obligations at prices that are governed by regulations adopted under an international agreement. Electric utilities operating under concessions in the Midwest, South and Southeast regions of Brazil are required by law to purchase a portion of Brazil’s share of Itaipu’s available capacity. In 2007, we purchased 10,990 GWh of electricity from Itaipu (22.8% of the electricity we purchased), as compared to 10,761 GWh of electricity from Itaipu (23.4% of the electricity we purchased) in 2006. See “Item 4. Information on the Company—Purchases of Electricity—Itaipu.” The price of electricity from Itaipu is set in U.S. dollars to reflect the costs of servicing its indebtedness. Accordingly, the price of electricity purchased from Itaipu increases in real terms when the real depreciates against the U.S. dollar. The change in our costs for Itaipu electricity in any year is subject to the Parcel A cost recovery mechanism described below.

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Our distribution subsidiaries are allowed by the MME to include in the Parcel A account (conta de compensação de variação de valores da parcela A), or CVA, the differences between the costs of acquiring electricity and the prices charged to our customers that were not taken into account in the prior year’s tariff adjustment. This adjustment should eliminate the difference in the income statement that originated from these variations. However, our cash flows may be adversely affected until the amounts under CVA are received in future years. Additionally, with the New Industry Model Law, the calculation method of the costs of acquired energy was changed, and now, with respect to new electricity contracts derived from auctions, the adjustment must reflect the electricity cost in the future reference market.

Through our generation subsidiaries, approximately 586 MW of new capacity is scheduled to become operational through 2010, with the commencement of operations of UHEs Castro Alves, 14 de Julho and Foz do Chapecó, which will provide additional Assured Energy of 2,579 GWh per year. Our distribution subsidiaries have entered into long-term contracts to purchase all of this electricity. We expect our margins to be higher to the extent our distribution companies resell electricity generated by our generation subsidiaries, because we will benefit from the generators’ margin.

Most of the electricity we acquired in the free market was purchased by our commercialization subsidiary CPFL Brasil, which resells that electricity to free consumers and other concessionaries and licensees (including our subsidiaries). In 2007 we acquired 18,488 GWh in the free market, or 38.4% of the electricity we purchased. See “ — The Brazilian Power Industry — The Free Market.”

Recoverable Cost Variations—Parcel A Costs

We use the CVA or the Parcel A account to recognize some of our costs in the distribution tariff, referred to as “Parcel A” costs, as beyond our control. These costs are described in Note 3(c) to our audited consolidated financial statements for the fiscal year ended December 31, 2007. When these costs are higher than the forecasts used in setting tariffs, we are generally entitled to recover the difference through subsequent annual tariff adjustments. Similarly, if Parcel A costs are lower than forecast, we generally pass through the savings to customers through lower tariffs in the future.

When there are variations in Parcel A costs that will be reflected in future tariffs, we defer the incremental costs and record them on our balance sheet as the CVA. We will recognize these amounts as expenses when we bill the related increased tariffs. At December 31, 2007, we had assets of R$738.3 million and liabilities of R$298.4 million in respect of Parcel A accounts, and the net amount represented 8.9% of our shareholders’ equity. These amounts accrue interest at a rate based on SELIC, a Brazilian money market rate. In 2007 we recognized R$68.3 million of net financial income on Parcel A accounts.

These assets and liabilities may be affected by regulatory determinations. In the first quarter of 2008, ANEEL determined that our subsidiary CPFL Paulista should not be permitted to recover some 2007 energy costs that it had capitalized as a regulatory asset related to “Energy surpluses and shortages”, on the grounds that the costs should have been avoided by different purchasing practices under a supply contract between CPFL Paulista and our subsidiary CPFL Brasil. The determination was made in the context of the periodic revision of CPFL Paulista’s tariffs, and it is still preliminary and subject to challenge. We also capitalized 2007 costs under similar circumstances at our subsidiary CPFL Piratininga, which also has a supply contract with CPFL Brasil. At December 31, 2007, the total regulatory assets arising from these costs at CPFL Paulista and CPFL Piratininga was R$ 109 million. In the first quarter of 2008, following ANEEL’s determination, we decided those assets were fully impaired and we recognized a provision to reimburse consumers, resulting in a total charge of R$112 million, net of taxes.

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The 2001-2002 Energy Crisis and Related Regulatory Measures

As a result of an energy crisis in Brazil in 2001 through 2002, the Brazilian Government and companies involved in the energy sector agreed to adopt a package of measures instituted to address some of the financial effects of the energy shortage. See Note 3 to our audited consolidated financial statements. The principal measures adopted in response to the 2001-2002 energy crisis are the following:

• Extraordinary Tariff Adjustment. Reajuste Tarifário Extraordinário, or RTE, is an extraordinary tariff adjustment designed to enable generation and distribution companies to recover the losses or revenue foregone during the Rationing Program that took place during the energy crisis. As of December 31, 2007, we included in our accounts receivable the balance of R$6.3 million expected recovery pursuant to the RTE. Part of this amount must be passed on to our suppliers to compensate them for the losses they incurred during the Rationing Program. The amounts recoverable and payable accrue interest, and in 2007 R$23.8 million of net financial income was attributable to such accounts receivable. As we receive the RTE amounts from our customers, we pass on to our suppliers the portion attributable to them. These transactions reduce the amount of receivables and payables on our balance sheet, but do not affect our statement of operations because the revenues and costs were previously recognized in 2001 and 2002. The effect on our cash flow is small because we received an advance of these funds from BNDES (as discussed below) in 2002 and, accordingly, the RTE we receive is used to service the debt on this loan.

• Parcel A Costs. As described above, certain variations in our Parcel A costs are recoverable through future tariffs. Increased Parcel A costs from 2001 are now being recovered through a mechanism similar to the RTE, as we recovered the foregone revenue from the Rationing Program.

• BNDES Loan Program. The Brazilian government made loans available to distribution and generation companies through the government development bank BNDES to finance (a) 90% of the revenue shortfall recoverable through the RTE and (b) the excess Parcel A costs from 2001. We had a total principal amount of R$142.2 million of these loans outstanding as of December 31, 2007. These loans accrue interest at the same rate as amounts we are entitled to recover pursuant to the RTE.

Deductions from Operating Revenues

To present net operating revenues, we deduct from our operating revenues a variety of taxes and regulatory charges, the most important of which is the value-added tax, or ICMS, imposed by Brazilian states. These deductions amounted to 33.8% of our gross operating revenues in 2007, 35.3% in 2006, and 35.9% in 2005.

Operating Segments

Our three reportable segments are distribution, generation and commercialization. See Note 35(iv)(c) to our audited consolidated financial statements. Our generation and commercialization segments currently represent a small percentage of our gross operating revenues: 2.3% and 6.3% in 2007 and 2.3% and 5.7% in 2006, respectively. We expect our generation business to grow as our projects come on line through 2010. Since the new electricity will be sold primarily to our distribution companies, on a consolidated basis the new generation may not materially increase our operating revenues, but we expect it to have a positive effect on our consolidated operating margin.

The profitability of our segments differs. Our generation segment consists in substantial part of new hydroelectric projects, which require a high level of investment in fixed assets, and in the early years there is typically a high level of construction financing. Once these projects are operational, they have higher margin (operating income as a percentage of revenue) than the distribution segment, but they also contribute to higher interest expense and other financing costs. For example, in 2007 and 2006 our generation segment provided 16.2% and 16.3%, respectively, of our operating income, but its contribution to our net income was substantially lower.

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In our commercialization segment, a majority of our sales and operating income is attributable to transactions with our distribution segment. In 2007, our commercialization segment sold 11.8% less electricity than in 2006, and sales to unaffiliated parties decreased by 2.1%, reaching 9,128 GWh. Sales to unaffiliated parties include sales of electricity to free consumers and other concessionaries or licensees and the provision of value-added services. This decrease in volume of sales, however, was offset by an increase in our prices.

Brazilian Economic Conditions

All of our operations are in Brazil, and we are affected by general Brazilian economic conditions. In particular, the general performance of the Brazilian economy affects demand for electricity, and inflation affects our costs and our margins. The Brazilian economic environment has been characterized by significant variations in economic growth rates, with very low growth from 2001 through 2003 and an economic recovery that has led to consistent growth since 2004. In particular,the following factors affected our operations:

• The real appreciated by 11.8% in 2005, 8.7% in 2006 and 17.2% in 2007 against the U.S. Dollar. As of April 23, 2008, appreciation of the real against to the U.S. Dollar was approximately 6.4% in 2008 year-to-date. Inflation for 2007, as measured by the IGP-M, was 7.8% .

• Brazilian GDP grew by 2.9% in 2005, 3.7% in 2006 and by 5.4% in 2007.

• The short-term average interest rate (adjusted by the Central Bank in relation to the SELIC index) decreased to 11.8% in 2007 from 15.1% in 2006 and from 19.1% in 2005.

The following table shows inflation, the change in real gross domestic product and the variation of the real against the U.S. Dollar for the years ended December 31, 2007, 2006 and 2005.

		Year ended December 31,
		2007		2006		2005
Inflation (IGP-M) (1)		7.8%		3.8%		1.2 %
Inflation (IPCA) (2)		4.5%		3.1%		5.7%
Growth (contraction) in real gross domestic product		5.4%		3.7%		2.9%
Depreciation (appreciation) of the real vs. U.S. dollar		(17.2)%		(8.7)%		(11.8)%
Period-end exchange rate–US$1.00		R$1.771		R$2.138		R$2.341
Average exchange rate–US$1.00 (3)		R$1.930		R$2.168		R$2.413

Inflation primarily affects our business by increasing operating costs and financial expenses to service our inflation-indexed debt instruments. We are able to recover a portion of these increased costs through the Parcel A cost recovery mechanism, but there is a lag in time between when the increased costs are incurred and when the increased revenues are received following our annual tariff adjustments. The amounts owed to us under Parcel A are indexed to the variation of the SELIC rate until they passed through to our tariffs.

Results of Operations—2007 compared to 2006

Operating revenues

Our net operating revenues were R$9,410 million in 2007, an 18.9% increase compared to 2006. The increase was due to higher volume and higher prices. Our total volume of electricity delivered to final customers increased by 7.2%, of which (a) 6.4% was attributable to the acquisitions of CPFL Santa Cruz, which we began consolidating in January 2007, and CPFL Jaguariúna, which we began consolidating in July 2007, and to the full consolidation of RGE beginning in June 2006 and (b) 0.8% was attributable to growth in our continuing businesses. The price increases were due to rate increases that resulted in a 7.6% increase in the average price (based on gross revenues) on sales to final customers.

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The same factors resulted in a 16.2% increase in our gross operating revenues. See “—Background—Deductions from Operating Revenues” for a discussion of items we deduct in arriving at net operating revenues.

In 2008, we expect our revenues, operating income and net income to be adversely affected by lower rates resulting from the periodic revision of our tariffs. See “—Background—Periodic Revision.” The magnitude of this impact on our operating income and net income will depend on our success in improving our margins through cost control, increased generation capacity, increased volume sold by our distribution subsidiaries and growth in the commercialization business.

Prices and volumes on sales to final customers

Our average prices in 2007 increased for all categories of final customers. Tariffs are adjusted each year. The month in which the tariff adjustment takes effect varies, with the increases in the largest subsidiaries taking effect in April (CPFL Paulista and RGE) and October (CPFL Piratininga). See “—Background—Regulated Distribution Tariffs.”

Our higher average prices in 2007 reflected annual adjustments in 2006 and 2007. The increase in average prices from 2006 to 2007 was 2.4%, 3.2% and 2.2% for residential, commercial and rural customers, respectively. Average prices increased for industrial customers by 13.9%, due mainly to the increase in sales prices applicable to industrial customers in the free market and tariff adjustments for captive customers. Industrial customers in concession areas who purchase in the free market also pay us for the use of our network, and this revenue is reflected in our consolidated financial statements under “Other Operating Revenues.”

The total volume of electricity sold to final customers, which was 40,324 GWh in 2007 compared to 37,602 GWh in 2006, increased for all categories of final customers except in the industrial sector, where it declined slightly (1.1%) .

Sales to distributors

Operating revenues from sales to unaffiliated distributors amounted to R$683 million in 2007 (4.8% of our gross operating revenues), an increase of 36.4% compared to 2006. The increase was due to sales to other concessionaires and licensees, which increased to R$285 million in 2007 from R$200 million in 2006, mainly because of the increase in prices applied by CPFL Brasil.

Other operating revenues

Our other operating revenues were R$1,169 million in 2007 (8.2% of our gross operating revenues), compared to R$827 million in 2006. This increase is due to an increase in electricity network usage charges (including the TUSD) of R$108 million, which is due primarily to an increase of energy consumption by customers that migrated to the free market. The increase is also due to the R$189 million write-off of our liability to pass on RTE revenues to suppliers, because a significant portion of the program of recovery of costs incurred from the 2001-2002 energy crisis ended in 2007. The revenue from this write-off was fully offset by an expense write-off for the corresponding asset. See Note 3(a) to our consolidated financial statements.

Operating Costs and Operating Expenses

Electricity purchased for resale

Our costs to purchase electricity amounted to R$4,052 million in 2007 (62.0% of our total operating costs and operating expenses). This was 18.5% higher than in 2006, primarily resulting from (i) a 4.7% increase in the volume of electricity we purchased and (ii) higher prices for purchases in the regulated market, free market purchases and purchases from Itaipu.

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The average price for all purchases excluding Itaipu was 11.8% higher in 2007 than in 2006, because of the effect of the annual tariff adjustment. The average price for electricity purchased from Itaipu, which represented 22.8% of the volume we purchased in 2007, was 8.6% higher in 2007 than in 2006. The increase in price reflected the increase in tariffs for Itaipu established by ANEEL.

In the aggregate, we purchased 4.7% more electricity in 2007 because of an increase in volume sold. This increase in purchased electricity, however, was not proportionate to the increase in volume of sales that was 7.2%, because we received additional energy from our own new plants that became operational in 2007. See “—Background—Prices for Purchased Electricity.” Note 24 to our audited consolidated financial statements provides a breakdown of our electricity purchase costs and volumes.

In the first quarter of 2008, we recognized a charge of R$112 million (net of taxes) because of a change in the amount of our regulatory assets and liabilities related to “Energy surpluses and shortages”. ANEEL determined that our subsidiary CPFL Paulista should not be permitted to recover some 2007 energy costs that it capitalized, and as a result we recorded an impairment of regulatory assets and recognized a regulatory liability. See Note 34 to our consolidated financial statement.

Electricity network usage charges

Our costs for electricity network usage charges were R$703 million in 2007. This was 9.2% lower than in 2006, due to the reduction in the net amount we recognized for Parcel A costs.

Other costs and expenses

Our other costs and expenses (other than electric utility service costs) were R$1,777 million in 2007, a 22.8% increase from 2006. This was due primarily to the write-off of our assets relating to the recovery of RTE costs, as discussed above, as well as our acquisition of new subsidiaries CPFL Jaguariúna, CPFL Santa Cruz, RGE and the entry into operations of Campos Novos, which contributed an additional R$113 million increase in expenses. See “—Use of Estimates in Certain Accounting Policies.”

Operating Income

Our operating income was R$2,878 million in 2007, as compared to R$2,272 million in 2006, due primarily to revenue growth, as discussed above.

Net Financial Expense

Our net financial expense was R$371million in 2007, compared to R$150 million in 2006. This was partly because 2006 net financial expense was favorably affected by the R$122 million reversal of provisions for PIS and COFINS from prior years, because we obtained a favorable resolution of our challenge to the application of those taxes to our financial income. The increase in net financial expense was also partly attributable to lower recognition of financial income on regulatory assets as the balance of those assets decreased. Except for these two effects, the effect of higher indebtedness was offset by the effect of lower rates.

At December 31, 2007, we had R$5,006 million in debt denominated in reais, which accrued both interest and monetary correction based on a variety of Brazilian indices and money market rates. We also had the equivalent of R$1,085 million of debt denominated in foreign currencies (U.S. dollars and Japanese yen). In order to reduce the risk of exchange losses with respect to these foreign-denominated debts, we entered into long-term currency swaps for a significant portion of these debts. The rates of index variation were lower in 2007, with the CDI decreasing to 11.8% in 2007 from 15.1% in 2006 and the TJLP decreasing to 6.4% in 2007 from 7.9% in 2006, which more than offset the effect of the increase in debt used for the expansion of our generation and distribution activities as well as our new acquisitions.

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Non-operating Income (Expense)

In 2007, we recorded non-operating expense of R$31 million, compared to a non-operating income of R$50 million in 2006. The change was mainly due to the realization of a gain in 2006 due to the sale of investments.

Income and Social Contribution Taxes

We recorded a net charge of R$828 million for income and social contribution taxes in 2007, compared to R$734 million in 2006. Our effective tax rate of 33.4% on pretax income in 2007 was approximately equal to the combined statutory rate of 34%. Our subsidiaries are not consolidated for tax purposes, and our tax rate may vary from year to year depending on rates attributed to individual subsidiaries.

Net Income

Our net income was R$1,643 million in 2007, an increase of 17.0% compared to 2006, due primarily to the higher volumes and margins of sales of electric energy and costs growing more slowly than revenues.

Results of Operations—2006 compared to 2005

Operating revenues

Our gross operating revenues increased from R$10,907 million in 2005 to R$12,227 million in 2006. This represented an increase of 12.1%, primarily due to the increase of 7.3% in average prices on sales to final customers and a 4.1% increase in the total volume of electricity delivered to final customers. Most of our gross operating revenues result from sales to final customers (R$11,034 million, or 90.2%, in 2006), and all of our customers experienced higher prices in 2006. As a result of our acquisition of the additional stake in RGE, our gross operating revenues increased by approximately R$470 million.

See Note 23 to our audited consolidated financial statements for a breakdown of revenues by category of final customer.

Our net operating revenues were R$7,912 million in 2006, a 13.2% increase compared to 2005. The principal reason for the increase was the 12.1% increase in gross operating revenues discussed above. See “—Background—Deductions from Operating Revenues” for a discussion of items we deduct when calculating net operating revenues.

Prices and volumes on sales to final customers

Our average prices in 2006 increased for all categories of final customers. Tariffs are adjusted each year in April for CPFL Paulista and RGE and in October for CPFL Piratininga. See “—Background—Regulated Distribution Tariffs.”

Our higher operating revenues in 2006 reflected annual adjustments in 2005 and 2006. The increase in average prices from 2005 to 2006 was 3.9%, 5.6% and 2.1% for rural, commercial and residential customers, respectively, as a result of tariff adjustments. Price increases for industrial customers averaged 10.8%, due mainly to tariff adjustments for captive customers in this category. This increase was partially offset by lower sales prices applicable to industrial customers in the free market due to competition and the fact that the average price in the free market does not reflect revenues from the TUSD.

The total volume of electricity sold to final customers, which was 37,602 GWh in 2006 compared to 36,135 GWh in 2005, increased for all categories of final customers except in the industrial sector, where it remained stable.

Sales to distributors

Operating revenues from sales to unaffiliated distributors amounted to R$501 million in 2006 (4.1% of our gross operating revenues), an increase of 8.8% compared to 2005. The increase was due primarily to sales to other concessionaires and licensees, consisting mainly of sales by CPFL Brasil, which increased to R$200 million in 2006 from R$123 million in 2005.

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Other operating revenues

Our other operating revenues were R$827 million in 2006 (6.8% of our gross operating revenues), compared to R$606 million in 2005, primarily reflecting an increase of R$219 million related to electricity network usage charges (including the TUSD). This increase is due primarily to the industrial customers that migrated to the free market.

Operating Costs and Operating Expenses

Electricity purchased for resale

Our costs to purchase electricity amounted to R$3,419 million in 2006 (60.6% of our total operating costs and operating expenses). This was 7.7% higher than in 2005, primarily resulting from (i) an increase in the volume of electricity we purchased and (ii) the net effect of price increases applicable to our long-term purchase contracts and lower prices for electricity from Itaipu, both of which were partially offset by recovery of Parcel A losses.

The average price for all purchases excluding Itaipu was 4.7% higher in 2006 than in 2005, because of the effect of the annual adjustment and the replacement of volume under our Initial Supply Contracts. The average price for electricity purchased from Itaipu, which represented 23.4% of the volume we purchased in 2006, was 2.2% lower in 2006 than in 2005. The drop in price reflected the rise in the value of the real against the U.S. dollar in 2006, which had a more significant impact than the increase in nominal prices.

In the aggregate, we purchased 6.4% more electricity in 2006 because of an increase in volume sold to final consumers and other concessionaires and licensees. See “—Background—Prices for Purchased Electricity.” Note 24 to our audited consolidated financial statements provides a breakdown of our electricity purchase costs and volumes.

Electricity network usage charges

Our costs for electricity network usage charges were R$774 million in 2006. This was 2.2% higher than in 2005, due to higher tariffs and increased use of the transmission grid.

Other costs and expenses

Our other costs and expenses (other than electric utility service costs) were R$1,447 million in 2006. This was 2.1% higher than in 2005, due primarily to the additional costs and expenses that we started to consolidate after acquiring an additional stake of RGE. Pension costs in 2006 were R$97.8 million lower than in 2005, as a result of changing assumptions resulting from the improved performance of plan assets. See “—Use of Estimates in Certain Accounting Policies.”

Operating Income

Our operating income was R$2,272 million in 2006, as compared to R$1,643 million in 2005, due primarily to revenue growth, despite higher operating expenses, as discussed above.

Net Financial Expense

Our net financial expense was R$151 million in 2006, compared to R$212 million in 2005. This 28.9% decrease reflected a reduction in financial expense, which was R$748 million in 2006 compared to R$816 million in 2005.

At December 31, 2006, we had R$4,389 million in debt denominated in reais, which accrued both interest and monetary correction based on a variety of Brazilian indices and money market rates. The lower financial expense in 2006 resulted primarily from (i) lower rates of index variation, with the CDI decreasing to 15.1% in 2006 from 19.1% in 2005 and the TJLP decreasing to 7.9% in 2006 from 9.8% in 2005 and (ii) the improvement of our debt profile.

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At December 31, 2006, we had the equivalent of R$682 million of debt denominated in foreign currencies (U.S. dollars and Japanese yen). In order to reduce the risk of exchange losses with respect to these foreign-denominated debts, we entered into long-term currency swaps for a significant portion of these debts. In 2006, our net financial expense decreased in part as a result of the lower CDI rate.

In addition, CPFL Paulista and CPFL Piratininga recorded PIS and COFINS credits of R$122 million under financial income in 2006 due to favorable final judgments in the legal proceedings challenging the legality of the increase in the calculation base for contributions to PIS and COFINS.

Non-operating Income

In 2006, we recorded non-operating income of R$50 million, compared to R$0.4 million in 2005. The increase was mainly due to the sale of equity interests held for investment.

Income and Social Contribution Taxes

We recorded a net charge of R$734 million for income and social contribution taxes in 2006, compared to R$336 million in 2005. Our effective tax rate of 33.8% on pretax income in 2006 was slightly lower than the combined statutory rate of 34%. However, it increased substantially from our temporarily low effective tax rate of 23.5% in 2005, when we were able to recognize a tax credit from a loss carryforward through our parent company based on expected taxable income in the future.

Extraordinary Item

In 2006, we recorded a charge of R$32.6 million for extraordinary item, net of R$16.7 million in taxes, which were exactly the same figures as in 2005. The charge resulted from a change in accounting for post-retirement benefits plans under Brazilian Accounting Principles. We recognized the initial effect of this change in income as an extraordinary item, net of taxes, over the five-year period from 2002 to 2006.

Net Income

Our net income increased to R$1,404 million in 2006 from R$1,021 million in 2005, due primarily to the increase in operating income, reflecting higher operating revenues, and the decrease in net financial expense.

Capital Expenditures

Our principal capital expenditures in the past several years have been for the maintenance and upgrading of our distribution network and for our generation projects. The following table sets forth our capital expenditures for the three years ended December 31, 2007, 2006 and 2005.

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		Year ended December 31,
		2007		2006		2005
				(in millions)
Distribution:
CPFL Paulista		R$ 291		R$ 245		R$ 189
CPFL Piratininga		144		131		86
RGE		221		151		93
CPFL Jaguariúna		9		-		-
CPFL Santa Cruz		11		-		-
Total distribution		676		527		368
Generation		445		266		255
Commercialization		9		4		4
Other Investments		3		-		-
Total		R$ 1,133		R$ 797		R$ 627

We plan to make capital expenditures aggregating approximately R$1,196 million in 2008 and approximately R$1,124 million in 2009. Of total budgeted capital expenditures over this period, R$1,505 million is for distribution and R$815 million is for generation. Part of these expenditures, particularly in generation projects, is already contractually committed. See “—Liquidity and Capital Resources—Funding Requirements and Contractual Commitments.” Planned capital expenditures for development of our generation capacity, and the related financing arrangements, are discussed in more detail under “Business—Generation of Electricity.”

Liquidity and Capital Resources

Funding Requirements and Contractual Commitments

Our capital requirements are primarily for the following purposes:

• We make capital expenditures to continue improving our distribution system and to complete our generation projects. See “—Capital Expenditures” above for a discussion of our historical and planned capital expenditures.

• We have required funding in 2006 and 2007 for major acquisitions and may make further acquisitions in the future. These acquisitions were not included in our budget for capital expenditures.

• We must repay or refinance maturing debt. At December 31, 2007, we had outstanding debt maturing during the following 12 months aggregating R$1,166 million.

• We pay dividends on a semiannual basis. We paid R$1,561 million in 2007 and R$1,090 million in 2006. See “Item 10. Additional Information—Interest Attributable to Shareholders’ Equity.”

On December 31, 2007, our working capital reflected a deficit (excess of current liabilities over current assets) of R$141 million. This deficit was principally due to our provision for dividend payments of R$744 million, and it was eliminated by cash generated from our operating activities during the first quarter of 2008. The dividend payment is scheduled to happen on April 30, 2008.

The following table summarizes our contractual obligations as of December 31, 2007. The table does not include accounts payable reported on our balance sheet.

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	Payments Due by Period
			Less than
	Total		1 year		1-3 years		4-5 years		After 5 years
	(in millions of reais)
Contractual obligations as of December 31, 2007:
Long term debt obligations(1)	R$6,091		R$1,017		R$2,197		R$1,277		R$1,600
Purchase obligations:
Electricity purchase agreements (2)	93,639		5,152		10,739		11,448		66,300
Generation projects	1,494		363		421		69		641
Supplies	675		406		255		8		6
Pension funding (3)	717		68		140		140		369
Total	R$102,616		R$7,006		R$13,750		R$12,923		R$68,937

Sources of Funds

We generate substantial cash from our operations, but it can vary from period to period as Parcel A costs change. Under our regulatory system, we regularly recover some of our increased costs from one period through tariff adjustments in future periods, and through 2007 we recovered some foregone revenues from July 2001 through February 2002 through the RTE. Net cash provided by operating activities was R$2,248 million in 2007, as compared to R$2,298 million in 2006.

Our debt increased in 2007 by R$1,021 million (excluding the effects of interest and derivatives transactions) and increased in 2006 by R$234 million. The main reasons for the increase in 2007 were the acquisition of CPFL Jaguariúna in June 2007, our posting of a judicial escrow required for a lawsuit to which we are a party (See Note 20 to our Financial Statements) and loans for the construction of generation plants. The primary reasons for the increase in 2006 were our acquisitions of the additional stake in RGE and 100% of CPFL Santa Cruz.

In October 2007, we issued R$450 million in non-convertible debentures to refinance the short-term debt incurred to acquire CPFL Jaguariúna. These debentures will become due in three annual installments beginning in September 2012 and bear interest at the rate of CDI + 0.45% per year.

In December 2007, RGE issued its third set of debentures. The issuance occurred in five series, each of which was comprised of a single set of debentures. The debentures were issued in order to improve RGE’s financial condition, provide liquidity for investments in fixed assets and repay debt that will mature in 2009. The total value of the issuance will be R$380 million. The first series of the debentures was issued in December 2007 for R$100 million, due in three annual installments beginning on December 1, 2011. The debentures bear interest at CDI + 0.60% per year.

In September 2007, Foz do Chapecó signed a loan agreement in the amount of R$1,656 million (our share represents R$844 million) with BNDES in order to finance the construction of Foz do Chapecó power plant. By December 31, 2007, R$ 245 million had been disbursed. This loan bears interest based on TJLP and will be paid in 192 monthly installments beginning October 2011.

In 2008, we expect to fund remaining construction of our generation projects by drawing on credit facilities and using cash from our operating activities. Major acquisitions could also cause a substantial increase in our debt. Our expectations could change if there is a significant change in the tariff system or in economic conditions in the power sector or in Brazil in general.

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In the first quarter of 2008, CPFL Geração entered into some Yen-denominated loan agreements in the aggregate amount of R$176 million for working capital needs. These loans bear interest at annual rates that vary from 2.5% to 5.8% and are due in January 2011. We have entered into swap agreements in order to reduce our exposure to interest rates that arises from these obligations.

Terms of Outstanding Debt

Total debt outstanding at December 31, 2007 (excluding accrued interest and derivative transactions) was R$6,090.9 million. Of the total amount, approximately R$1,085.0 million, or 17.8%, was denominated in U.S. dollars and Japanese yen, and the balance was denominated in reais. R$1,017.3 million of our total debt is scheduled to mature in the next 12 months.

Our major categories of indebtedness are as follows:

• BNDES. At December 31, 2007, we had approximately R$2,051.5 million outstanding under a number of facilities provided through BNDES. These loans are denominated in reais.

The most significant part of these loans (a total of R$1,909.3 million at December 31, 2007) relate to (a) loans to our generation projects, (b) financing for the renewal of older generation assets and (c) financing of investment programs of our subsidiaries CPFL Paulista, CPFL Piratininga and RGE, through lines of credit under the BNDES – FINEM loan facility.

The remainder of our borrowing from BNDES (a total of R$142.2 million at December 31, 2007) relates to Parcel A costs and revenue losses arising in connection with the Rationing Program and bears interest at an annual rate of 1% over the SELIC rate.

• Debentures. At December 31, 2007, we had indebtedness of approximately R$2,363.1 million outstanding under nine series of debentures issued by CPFL Energia, CPFL Paulista, CPFL Piratininga, CPFL Geração, BAESA and RGE. The terms of these debentures are summarized in Note 17 to our audited consolidated financial statements.

• Other real-Denominated Debt. As of December 31, 2007, we had R$591.2 million outstanding under a number of other real-denominated facilities secured by the revenues of the borrower. The majority of these loans are restated based on CDI or IGP-M, and bear interest at various rates.

• Yen-Denominated Debt. CPFL Paulista, CPFL Energia, RGE and CPFL Geração entered into bilateral loans denominated in yen and converted to reais through swap agreements based on CDI. As of December 31, 2007, the total outstanding principal amounts for these loans were R$402.7 million for CPFL Paulista, R$171.2 million for CPFL Energia, R$ 27.1 million for RGE and R$298.8 for CPFL Geração.

• IDB Loan. In January 2005, ENERCAN signed a loan agreement with the Inter-American Development Bank (IDB) for US$75 million to finance the Campos Novos hydroelectric power plant. At December 31, 2007, our pro-rata share of this loan was US$35.3 million (equivalent at the time to R$62.5 million). The loan bears interest at a rate of LIBOR plus 3.5% per annum. The repayment terms are spread over 49 quarterly installments, with an initial grace period that ended in June 2007.

• Other Foreign-Denominated Debt. At December 31, 2007, we had R$122.6 million outstanding under other loans denominated in U.S. dollars. We have entered into swap agreements in order to reduce our exposure to exchange rates that arises from these obligations. In addition, we have U.S. dollar-denominated long-term receivables, which amounted to R$27.2 million (R$45.5 million including current assets) at December 31, 2007, which also mitigate our exposure to exchange rates.

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Financial and Operating Covenants

We are subject to financial and operating covenants under our financial instruments and those of our subsidiaries. These covenants include the following:

• We have limitations on our ability to sell or pledge assets or to make investments in third parties.

• Under the BNDES credit facilities, our subsidiaries must first pay the amounts due under the loans before paying dividends in an amount higher than the mandatory dividends under Brazilian law. In addition, before making these dividend payments and before paying interest on shareholders’ equity, BNDES must give its prior approval, and the respective subsidiary must be in compliance with all of its financial covenants.

• Under the second issuance of CPFL Paulista debentures, CPFL Paulista must maintain a ratio of EBITDA to financial expenses of at least 1.5 and a ratio of capital to total capitalization of at least 40%, with the ratios calculated as defined in the CPFL Paulista debentures.

• Under the third issuance of CPFL Paulista debentures, CPFL Paulista must maintain a ratio of net indebtedness to EBITDA of less than 3.0 and a ratio of EBITDA to financial expense, net, of at least 2.25, with the ratios calculated as defined in the CPFL Paulista debentures.

• Under the RGE debentures, RGE must maintain a ratio of indebtedness to EBITDA of less than 3.0, a ratio of EBITDA to financial expenses of at least 2.0 and a ratio of indebtedness to total capitalization of less than 55%, with the ratios calculated as defined in the RGE debentures.

• Under the CPFL Piratininga debentures, CPFL Piratininga must maintain a ratio of net indebtedness to EBITDA of less than 3.0 and a ratio of EBITDA to financial results of at least 2.25, with the ratios calculated as defined in the CPFL Piratininga debentures.

As a result of the postponement of the commercial start-up of Campos Novos hydroeletric plant, we were not able to meet some time sensitive covenants of the IDB Loan. Enercan’s management has already entered into discussions with the relevant financial institutions in order to review those covenants, and has obtained a confirmation that these institutions will not seek acceleration of the loan agreement.

Otherwise, we are currently in compliance with our financial and operating covenants. Breach of any of these covenants would give our lenders the right to accelerate our repayment obligations.

In addition, a number of our financing instruments are subject to acceleration if our current shareholders cease to own a majority of CPFL Energia’s voting equity or otherwise control the management and policies of the company, or if VBC ceases to own, directly or indirectly, at least 25% of CPFL Paulista’s issued and outstanding capital stock.

Our Campos Novos, Barra Grande and CERAN generation projects are restricted from paying dividends under their financing agreements (as established with BNDES). The concessions for our distribution and generation subsidiaries prohibit them from making loans or advances to us or to our other subsidiaries and affiliates without approval from ANEEL. Most of our debt instruments also provide that if there is a default under a covenant, the company in question will be limited in its ability to pay dividends in excess of the legal minimum under Brazilian law.

For more information on our financial covenants, see Notes 16 and 17 to our audited consolidated financial statements.

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Research and Development and Electricity Efficiency Programs

In accordance with applicable Brazilian law, since June 2000 companies holding concessions, permission and authorizations for distribution, generation and transmission of electricity have been required to dedicate a minimum of 1% of their net operating revenue each year to research and development and electricity efficiency programs. Small Hydroelectric Power Plant and wind, sun and biomass energy projects are not subject to this requirement. Beginning in April 2007, our distribution concessionaires dedicated 0.5% of their net operating revenue to research and development and 0.5% to electricity efficiency programs, while our generation concessionaries dedicated 1.0% of their net operating revenue to research and development.

Our electricity efficiency program is designed to foster the efficient use of electricity by our customers, to reduce technical and commercial losses and offer products and services that improve satisfaction and loyalty and enhance our corporate image. Our research and development programs utilize technological research to develop products, which may be used internally, as well as sold to the public. We carry out certain of these programs through strategic partnerships with national universities and research centers, and the vast majority of our resources are dedicated to innovation and development in new technologies applicable to our business.

Our disbursements on research and development projects in 2007 totalled R$115.5 million, compared to R$65.7 million in 2006 and R$38 million in 2005.

Off-Balance Sheet Arrangements

We have guaranteed some of the debt of our proportionately consolidated subsidiaries. These guarantees are generally of a proportion of the debt that is no greater than our proportionate ownership share of the subsidiary. However, we have guaranteed the full amount payable of credit facilities (not all of which has been drawn) of our subsidiary CERAN, while we only report our proportionate 65% share of the liabilities on our balance sheet. The outstanding balance of these obligations was R$650.3 million in as of December 31, 2007. In 2005 we assumed an obligation to guarantee 57.27% of the amount payable under a US$75 million credit facility of our subsidiary ENERCAN during the construction of its facilities, while we only report our proportionate 48.72% share of the liabilities on our balance sheet. Additionally, in 2007 we assumed an obligation to guarantee 60% of the amount payable under a R$480 million credit facility of our subsidiary Foz do Chapecó during the construction of its facilities, while we only report our proportionate 51% share of the liabilities on our balance sheet.

As of December 31, 2007, we had no: (a) guarantee obligations (as described in paragraph 3 of FASB Interpretation No. 45, Guarantor’s Accounting and Disclosure Requirements for Guarantees), other than the CERAN, ENERCAN and Foz do Chapecó guarantees described above; (b) retained or contingent interests in assets transferred to an unconsolidated entity or similar arrangements; (c) obligations under derivative instruments that are indexed to our common shares and classified in shareholders’ equity; or (d) obligations arising out of a variable interest in an unconsolidated entity, as defined in FASB Interpretation No. 46, Consolidation of Variable Interest Entities.

U.S. GAAP Reconciliation

We prepare our financial statements in accordance with Brazilian Accounting Principles, which differ in significant respects from U.S. GAAP. The differences are described in Note 35 to our audited consolidated financial statements. Net income for 2007 was R$1,675.4 million under U.S. GAAP, compared to R$1,643.4 million under Brazilian Accounting Principles. Shareholders’ equity at December 31, 2007 was R$6,891.8 million under U.S. GAAP, compared to R$4,954.8 million under Brazilian Accounting Principles.

The differences between Brazilian Accounting Principles and U.S. GAAP that have the most significant effects on net income and shareholders’ equity are the following:

• The difference in accounting for acquisitions under Brazilian Accounting Principles and U.S. GAAP. Under Brazilian Accounting Principles, acquisitions are accounted for at book value, and the difference between the book value of the purchased company’s net assets and the purchase price is recorded as goodwill and amortized. Under U.S. GAAP, the purchase price of an acquired entity is allocated to assets acquired, including identifiable intangible assets, and liabilities assumed based on their estimated fair values on the date of acquisition. The excess of the cost of an acquired entity over the net of the amount assigned to assets acquired and liabilities assumed is recognized as goodwill. Goodwill is not amortized under U.S. GAAP, subject to an annual assessment for impairment. However, under U.S. GAAP we principally allocated the excess purchase price over the fair value of assets acquired and liabilities to the concessions of the acquired companies, which is being amortized over the lives of the concessions. The net effect of these differences tended to make U.S. GAAP net income higher than Brazilian Accounting Principles net income when the amortization of goodwill under Brazilian Accounting Principles occurred over a 10-year period. Since 2004, we have been required to amortize goodwill over the lives of our concessions, which tends to increase net income under Brazilian Accounting Principles compared to U.S. GAAP.

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• The recognition of deferred tariff revenues through the RTE is limited under U.S. GAAP to amounts we expect to recognize over the next 24 months. This difference made U.S. GAAP net income higher in 2005 and previous years.

Use of Estimates in Certain Accounting Policies

In preparing our financial statements, we make estimates concerning a variety of matters. Some of these matters are highly uncertain, and our estimates involve judgments we make based on the information available to us. We have discussed certain accounting policies relating to regulatory matters above, in “—Background.” In the discussion below, we have identified several other matters for which our financial presentation would be materially affected if either (a) we used different estimates that we could reasonably have used or (b) in the future we change our estimates in response to changes that are reasonably likely to occur.

The discussion addresses only those estimates that we consider most important based on the degree of uncertainty and the likelihood of a material impact if we used a different estimate. There are many other areas in which we use estimates about uncertain matters, but the reasonably likely effect of changed or different estimates is not material to our financial presentation. Please see the notes to our audited consolidated financial statements included herein for a more detailed discussion of the application of these and other accounting policies.

Impairment of Long-lived Assets

Long-lived assets, which include property, plant and equipment, goodwill and investments comprise a significant amount of our total assets. We carry balances on our balance sheet that are based on historical costs net of accumulated depreciation and amortization. We are required under both Brazilian Accounting Principles and U.S. GAAP to evaluate periodically whether these assets are impaired, that is, whether their future capacity to generate cash does not justify maintaining them at their carrying values. If they are impaired, we are required to recognize a loss by writing off part of their value. The analysis we perform requires that we estimate the future cash flows attributable to these assets, and these estimates require us to make a variety of judgments about our future operations, including judgments concerning market growth and other macroeconomic factors as well as the demand for electricity. Changes in these judgments could require us to recognize impairment losses in future periods. Our evaluations in 2007 and 2006 did not result in any significant impairment of our property, plant and equipment or consolidated goodwill and investments.

Valuation of Deferred Regulatory Assets

As discussed above, we defer and capitalize Parcel A costs that we expect to recover through rate increases, and in 2001 and 2002 we recognized revenues that we will realize in future years pursuant to the RTE. We take this approach under Brazilian Accounting Principles, and under U.S. GAAP it is also consistent with SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation”. This statement provides that rate-regulated entities account for and report assets and liabilities consistent with the recovery of those costs in rates, if the rates established are designed to recover the costs of providing the regulated service and if the competitive environment makes it probable that such rates can be charged and collected. Certain expenses and revenues subject to utility regulation or rate determination normally reflected in income are deferred on the balance sheet and are recognized in income as the related amounts are included in service rates and recovered from or refunded to customers. The total amount of net deferred regulatory assets reflected in the consolidated balance sheets, including interest we have recognized, was R$572.8 million at December 31, 2007. See Note 3 to our audited consolidated financial statements. Under U.S. GAAP, we only recognize the deferred revenues to the extent we expect to recover them over the next 24 months.

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We are entitled to recover these costs through Brazilian regulations. ANEEL performs a rate review on an annual basis. If ANEEL excludes all or part of a cost from recovery, that portion of the deferred regulatory asset is impaired and is accordingly reduced to the extent of the excluded cost. As of December 31, 2007, the provision for losses upon the realization of this asset was R$16.6 million. This provision was made based on income projections prepared periodically, taking into account expectations regarding market growth, inflation, interest rates and regulatory matters. See Note 3 to our audited consolidated financial statements for the year ended December 31, 2007.

The deferral and capitalization of expenses, and the recognition and deferral of revenues, in this manner is based on our judgment that we will in fact recover the amounts under future rate increases. If our judgment as to the likelihood of recovery changes, we could be required to recognize an impairment of these regulatory assets.

Pension Liabilities

We sponsor pension plans and disability and death benefit plans covering substantially all of our employees. We account for these benefits in accordance with Brazilian Accounting Principles. The determination of the amount of our obligations for pension benefits depends on certain actuarial assumptions. Beginning in 2004, three of these assumptions were modified in accordance with the findings of a study by Fundação CESP – the mortality table, inflation rates and the expected nominal rate of return on plan assets – which in the aggregate tend to reduce the amount of our obligations. The results of this study will be reviewed annually. The total amount of our obligations recognized as revenues in 2007 was R$46.9 million. In 2008, the pension plan is expected to generate a surplus, and we expect to recognize an estimated credit of R$84.1 million in our results of operations. The three changes described above and the rest of the actuarial assumptions, including the discount rate applied to future obligations and increases in salaries and benefits, are described in Note 18. The differences between Brazilian Accounting Principals and U.S. GAAP are described in Note 35 to our audited consolidated financial statements.

Deferred Tax Assets and Liabilities

We account for income taxes in accordance with Brazilian Accounting Principles, which are similar to SFAS No. 109 “Accounting for Income Taxes,” which requires an asset and liability approach to recording current and deferred taxes. Accordingly, the effects of differences between the tax basis of assets and liabilities and the amounts recognized in our financial statements have been treated as temporary differences for the purpose of recording deferred income tax.

We regularly review our deferred tax assets for recoverability. Under Brazilian Accounting Principles, the tax asset is not recognized if it is more likely than not that it will not be realized. Under U.S. GAAP, we establish a valuation allowance based on historical taxable income, projected future taxable income, and the expected timing of the reversals of existing temporary differences. If we are unable to generate sufficient future taxable income, or if there is a material change in the actual effective tax rates or time period within which the underlying temporary differences become taxable or deductible, we could be required to establish a valuation allowance against all or a significant portion of our deferred tax assets resulting in a substantial increase in our effective tax rate and a material adverse impact on our operating results.

Reserves for Contingencies

We and our subsidiaries are party to certain legal proceedings in Brazil arising in the normal course of business regarding tax, labor, civil and other issues.

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We account for contingencies in accordance with Brazilian Accounting Principles, which are similar to SFAS No. 5, “Accounting for Contingencies.” Such accruals are estimated based on historical experience, the nature of the claims, as well as the current status of the claims. The evaluation of these contingencies is performed by various specialists, inside and outside of the company. Accounting for contingencies requires significant judgment by management concerning the estimated probabilities and ranges of exposure to potential liability. Management’s assessment of our exposure to contingencies could change as new developments occur or more information becomes available. The outcome of the contingencies could vary significantly and could materially impact our consolidated results of operations, cash flows and financial position. Management has applied its best judgment in applying SFAS No. 5 to these matters. Under U.S.GAAP the company adopted the provisions of FIN 48 and recognizes income tax positions only if those positions are more likely than not of being sustained, as described in Note 35 (iii)(o) of our consolidated financial statements.

Depreciation

We account for depreciation using the straight-line method, at annual rates based on the estimated useful life of assets, in accordance with ANEEL regulations and industry practice adopted in Brazil. Under U.S. GAAP, our property, plant and equipment are also depreciated using the straight-line method. However, the annual rates used to depreciate these assets are based on remaining useful life in accordance with the most recent appraisal report established for the assets acquired in a business combination. For the assets acquired after that date, the annual rates used to depreciate are those established by ANEEL. When a business combination occurs and the remaining useful life of an asset is changed, it may cause a material adverse impact on our results of operations in the period in which that estimate is revised and in the subsequent periods.

ITEM 6. DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES

Directors and Senior Management

Board of Directors

Our Board of Directors is responsible for determining our overall strategic guidelines and, among other things, for establishing our general business policies and for electing our executive officers and supervising their management. According to our bylaws, our Board of Directors may be comprised of a minimum of 7 members and a maximum of 9 members. Currently, our Board of Directors is comprised of seven members, and one is independent (in accordance with the listing regulations of the New Market of the BOVESPA, or the Novo Mercado, and our bylaws). In the event of a tie, the chairman will have the deciding vote. The Board of Directors meets at least once a month, or whenever requested by the chairman in accordance with our bylaws.

Under Brazilian Corporate Law, each director must hold at least one of our common shares. Under our bylaws, the board members are elected by the holders of our common shares at the annual general meeting of shareholders. Board members serve one-year terms, reelection being permitted provided that they may be removed at any time by our shareholders at an extraordinary general meeting of shareholders. Our current directors were elected at our general shareholders’ meeting held on April 9^th, 2008. Their terms will expire at our next annual shareholders’ meeting. Our bylaws do not provide for a mandatory retirement age for our directors.

Under Brazilian Corporate Law, if a director or an executive officer has a conflict of interest with the company in connection with any proposed transaction, the director or executive officer may not vote in any decision of the Board of Directors, or of the board of executive officers, regarding such transaction, and must disclose the nature and extent of the conflicting interest for transcription in the minutes of the meeting. A director or an executive officer may not transact any business with a company, including accepting any loans, except on reasonable or fair terms and conditions that are identical to the terms and conditions prevailing in the market or offered by third parties. Any transaction entered into between our shareholders or related parties and us that exceeds R$5 million, as adjusted annually by the IGP-M index, must be previously approved by our Board of Directors. As of this date, there are no relevant agreements or other obligations between us and our directors.

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Under Brazilian Corporate Law, combined with a recent decision by the Brazilian Securities Commission (Comissão de Valores Mobiliários, or CVM), minority shareholders have the right to designate at least one member of our board of directors for election to the board, provided that they hold at least 10% of the outstanding voting shares. Minority shareholders that own greater than 5% of voting shares may request voto múltiplo (multiple voting).

The following table sets forth the name, age and position of each current member of our Board of Directors. A brief biographical description of each of our directors follows the table.

Name		Age		Position
Luiz Anibal de Lima Fernandes		65		Chairman
Cecília Mendes Garcez Siqueira		50		Vice-President
Francisco Caprino Neto		48		Director
Otávio Carneiro de Rezende		53		Director
Milton Luciano dos Santos		51		Director
Carlos Alberto Cardoso Moreira		48		Director
Ana Dolores Moura Carneiro de Novaes		46		Independent Director

Luiz Anibal de Lima Fernandes – Mr. Fernandes received a degree in Mechanical and Electric Engineering from the Federal University of Minas Gerais (UFMG) in 1965. He completed additional coursework in Electrical Systems at the UFMG in 1966, Business Policy at Arthur D. Little/INDI – Instituto de Desenvolvimento Industrial de Minas Gerais, or INDI, in 1974, Marketing Strategy at the Fundação João Pinheiro in 1977, in Information Systems for Executives at IBM in 1982 and Advanced Development Strategies for Executives at the Fundação Dom Cabral/INSEAD in 2000. Mr. Fernandes was an engineer and executive at CEMIG from 1966 to 1975, President of the INDI from 1975 to 1979 and President and a board member of the BDMG – Banco de Desenvolvimento de Minas Gerais from 1979 to 1983. He was also the Finance and Institutional Investors Officer at CEMIG from 1983 to 1987 and Financial Controller at Siderbrás – Siderurgia Brasileira S.A. from 1987 to 1989. He was the Economic/Financial Officer, Investment Relations Officer and a member of the Board of Directors at Eletrobrás – Centrais Elétricas Brasileiras S.A. from 1989 to 1990, and he was the Director of Development at Mendes Junior Participações S.A. from 1990 to 1993. Mr. Fernandes was a partner and officer at Energia e Finanças Consultoria Ltda. from 1994 to 1995 and Chief Executive Officer (2002-2005), Financial and Investment Relations Officer (1996-2002) and Development Officer (1995-1996) at Acesita S.A. and Superintendent Director of VBC Energia S.A. (2007-2008). Since 2005, he has been the Managing Partner of L.A. & Associados – Participações e Negócios Ltda. He has been the Chairman of our Board of Directors since April 25, 2007.

Cecília Mendes Garcez Siqueira – Ms. Siqueira received a degree in Psychology from the University of São João Del Rey, in the State of Minas Gerais, and in Education from the University of Brasília – UNB, in 1998, and both a post-graduate degree in Social Security and Management of Pension Funds and a masters degree in Executive Management from Fundação Getúlio Vargas – FGV. She also received a Masters in Business Administration from the Instituto Brasileiro de Mercado de Capitais – IBMEC in 2007. Ms. Siqueira has been an employee of Banco do Brasil since 1979 and was appointed to work at PREVI, where she was a member of the Deliberative Board and has acted as the Planning Director since 2004. Ms. Siqueira was a member of the Board of Directors of Neoenergia until April 2005, and she was the Vice Chairman of the board of directors of CPFL Paulista, CPFL Piratininga and CPFL Geração until April 2006. Ms. Siqueira has been the Vice Chairman of our Board of Directors since April 29, 2005.

Francisco Caprino Neto – Mr. Caprino Neto received a degree in Metallurgic Engineering from the University of São Paulo-USP in 1983. He received a masters degree in Metallurgic Engineering from the same university in 1992.

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During his career, Mr. Caprino Neto held key positions in several private entities, such as Chief of the Engineering of Processes Department and Control and Planning Manager of Siderúrgica J.L. Aliperti S.A., Coordinator of Metallurgic Processes of Aços Villares S.A. and Planning Consultant of Camargo Corrêa S.A. He is currently the CEO of the concessions division of Camargo Corrêa Group, and a member of the Board of Directors of VBC Energia S.A. and Companhia de Concessões Rodoviárias-CCR. He was previously a member of the Board of Directors of CPFL Paulista, CPFL Piratininga, CPFL Geração and RGE and Chairman of the Board of Directors of CCR (2007 fiscal year). Mr. Caprino Neto has been a member of our Board of Directors since April 28, 2000.

Otávio Carneiro de Rezende – Mr. Carneiro de Rezende received a degree in Economics from the Faculdade Cândido Mendes, and a Masters in Business Administration from APG Amana Key in 1993. From 1985 to 1993, he worked at Banco Bozano Simonsen, and from 1993 to 1995, he worked at Banco Nacional. He was the Financial and Investor Relations Officer at Serra da Mesa Energia S.A. from 1996 to 1998 and at Bandeirante Energia S.A. from 1998 to 2000. Mr. Carneiro de Rezende was the Financial Officer of CPFL Paulista, CPFL Piratininga and CPFL Geração from 2000 to 2002. He is currently an officer of Votorantim Energia Ltda. and a member of the Board of Directors of VBC Energia, Consórcio Empresarial Pai Querê, Consórcio Empresarial Salto Pilão, Machadinho Energética, ENERCAN, BAESA, Amador Aguiar I e II and ABIAPE – Associação Brasileira de Investidores em Autoprodução de Energia Elétrica. Mr. Carneiro Rezende has been a member of our Board of Directors since December 18, 2002.

Milton Luciano dos Santos – Mr. Santos received a degree in Law from the University of Vale do Itajaí in 2001 and a Masters of Business Administration in Experienced Executive Training from the Federal University of São Paulo in 1994. He has worked at Banco do Brasil since 1976, where he has held the positions of Adjunct Manager from 1976 to 1979, General Manager from 1979 to 1994, State Superintendent from 1994 to 2004, Government Superintendent from 2004 to 2005, and Distribution Director from 2005 to 2007. He is currently Retail and Distribution Vice President. He has been a member of the Deliberative Council of the Brazilian Support Service for Small and Medium Enterprises (SEBRAE) in the States of Mato Grosso and Santa Catarina. Mr. Santos was also a member of the Board of Directors of EADI – Porto Belo S.A. for three years and of Centrais Elétricas de Santa Catarina S.A. (CELESC) from 1999 to 2001. Mr. Santos has been a member of our Board of Directors since December 18, 2006.

Carlos Alberto Cardoso Moreira – Mr. Moreira received a degree in Business Administration from Pontifical Catholic University of of São Paulo in 1984 and attended several extention courses, seminars and workshops on Previdência Complementar and Capital Market (IBMEC, IBC, ABRAPP, Wharton School). He has held the position of Senior Investment Analyst at Credibanco from 1984 to 1988, Resident Vice President of Citibank N.A., from 1988 to 1992, and Institucional Customers Director of Banco BMC S/A, from 1992 to 1999. Since 2002 he has been the Investiment and Finance Director of Fundação Sistel de Seguridade Social – SISTEL. He was also the Administrative Director of Bonaire Participações S.A., a member of the National Technical Commission of Investiments – CNTI, and a member of the Board of Directors of GTD Participações S.A., EMBRAER. He is currently a member of the Board of Directors of Paranapanema Group, Eluma, and Caraíba Metais. Mr. Moreira was a deputy member of our Board of Directors in 2007 and has been an effective member of our Board of Directors since April 9, 2008.

Ana Dolores Moura Carneiro de Novaes – Ms. Novaes has been a partner of Galanto Consultoria in Rio de Janeiro for services and consultancy in the area of corporate governance since 2008. She received a doctorate in Economics from the University of California, Berkeley in 1990 and a B.A. in Law at the Pontifical Catholic University of Rio de Janeiro in 2007. In 1998, she acquired the right to use the designation CFA, Chartered Financial Analyst, granted by the AIMR (Association for Investment and Management Research) in the USA. Ms. Novaes worked at the World Bank in Washington, D.C. between 1991 and 1994. From 1995 to 1997, she was an equity analyst at Banco de Investimentos Garantia and from 1998 to 2003 she was Investment Director of Pictet Modal Asset Management She also taught macroeconomics at the Pontifical Catholic University of Rio de Janeiro in 2003 and at the Federal University of Pernambuco in 1991. She is currently a member of the Board of Directors of Companhia de Concessões Rodoviárias (since May 2002), Datasul (since April 2006), and CPFL Energia (since April 2007), and a consultant to the Auditing Committee of Companhia Siderúrgica Nacional (since August 2006). Ms. Novaes has been a member of our Board of Directors since April 2007.

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Executive Officers

Our executive officers are responsible for our day-to-day management. Under our bylaws, our board of executive officers is comprised of seven members that are appointed by our Board of Directors for a two-year term, with the possibility of re-election. Our current executive officers were elected at the Board of Directors meeting held on April 25, 2007.

The following table sets forth the name, age and position of each current executive officer. A brief biographical description of each of our executive officers follows the table.

Name		Age		Position
Wilson Ferreira Junior		48		Chief Executive Officer
José Antonio de Almeida Filippo		47		Chief Financial Officer and Head of Investor Relations
Hélio Viana Pereira		54		Vice-President of Distribution
Miguel Normando Abdalla Saad		57		Vice-President of Generation
Paulo Cezar Coelho Tavares		54		Vice-President of Energy Management
Reni Antonio da Silva		57		Vice-President of Strategy and Regulation
José Marcos Chaves de Melo		45		Vice-President Administrative

Wilson Ferreira Junior – Mr. Ferreira Junior graduated in Electrical Engineering from Mackenzie University, City of São Paulo, in 1981. He also holds a graduate degree in Business from the same university (1983) and completed graduate studies in Energy at the University of São Paulo – USP. Mr. Ferreira Junior participated in several specialization programs, such as Workplace Safety Engineering from Mackenzie University, City of São Paulo, in 1982, Marketing from Fundação Getúlio Vargas in 1988 and Electricity Distribution Management from Swedish Power Co., Sweden, in 1992. He has acted in several key positions in Companhia Energética de São Paulo – CESP, an electric power producer in the Brazilian State of São Paulo, where he was the Distribution Executive Officer from 1995 to 1998. From 1998 to 2000, he was CEO of RGE, and from 2000 to 2001 he was Chairman of the Board of Directors of Bandeirante Energia. He was elected President of the Associação Brasileira de Distribuidores de Energia Elétrica — ABRADEE and he is the Vice President of the Associação Brasileira de Infra-Estrutura e Indústrias de Base – ABDIB, a non-profit organization that promotes infrastructure and industrial development in Brazil. Mr. Ferreira Junior is currently a member of the Board of Directors of ONS and a Vice President of the Fundação Nacional de Qualidade- FNO. In March 2000, he was appointed CEO of CPFL Paulista and was subsequently appointed our CEO and of a number of our subsidiaries including CPFL Jaguariúna, CPFL Piratininga, RGE, CPFL Santa Cruz, CPFL Brasil and CPFL Geração, among others. He has also been appointed as member of the Board of Directors of several of our subsidiaries, including CPFL Jaguariúna, CPFL Paulista, CPFL Piratininga, RGE, and CPFL Geração, among others. Mr. Ferreira Junior has been our CEO since August 28, 2002.

José Antonio de Almeida Filippo – Mr. Filippo graduated in Civil Engineering from the Federal University of Rio de Janeiro in 1983. He also holds a post-graduate degree in Finance from the Management and Administration Institute of the Catholic University of Rio de Janeiro (1984). He took part in the PDG at the Brazilian Institute of Capital Markets (IBMEC) (1990) and in the Program for Management Development at Harvard Business School (1999). Mr. Filippo was a financial officer of Gafisa Imobiliária S.A. from 1982 through 1995, the Corporate Financial Manager of Reynolds Latas de Alumínio S.A. – LATASA from 1995 through 2000 and the Chief Financial Officer for Latin America of Ingersoll-Rand Company from March 2000 through June 2004. Mr. Filippo was elected as the Chief Financial Officer and Head of Investor Relations of CPFL Energia, CPFL Paulista, CPFL Piratininga and CPFL Geração on June 30, 2004. He is also Chief Financial Officer of CPFL Brasil, CPFL Santa Cruz, CPFL Jaguariúna and he is a member of the Board of Directors of RGE, CERAN, ENERCAN, and Foz do Chapecó, among other of our subsidiaries. Mr. Filippo has been our CFO since July 30, 2004.

Hélio Viana Pereira – Mr. Pereira received a degree in Electric Engineering from Escola Federal de Engenharia de Itajubá – EFEI in 1976, and has a specialization degree in Industrial Quality Engineering from University of Campinas, State of São Paulo. He also received postgraduate degrees in Energy Business Management from Fundação Getúlio Vargas and University of São Paulo-USP. He was an engineer at the Rural Electric Department of Eletrobrás from 1976 to 1978. He was an engineer at the Underground Network Study Department and manager at the Public Illumination Division of Companhia de Electricidade de Brasília from 1978 to 1981 and acted in key positions as Operational Control Supervisor and Operation Manager at Companhia de Electricidade de Brasília from 1984 to 1989. Mr. Pereira held the position of Manager of the Department of Planning and Modernization at CPFL Paulista from May to August of 2000. He has held the position of Vice-President of Distribution at CPFL Paulista and CPFL Piratininga since September 2000 and, subsequently, Director of Distribution at CPFL Santa Cruz and CPFL Jaguariúna. Mr. Pereira has been our Vice-President of Distribution since August 28, 2002. He is also a member of the Board of Directors of CPFL Geração, among other of our subsidiaries.

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Miguel Normando Abdalla Saad – Mr. Saad received a degree in Civil Engineering from University of São Paulo-USP in 1973. He acted in several key positions at Companhia Energética de São Paulo – CESP, from 1974 to 2000, such as Chief Engineer of the Concrete Division of the Laboratory of Civil Engineering, Manager of the Division of Water and Thermal Resources, Adjunct Manager of the Electrical System Expansion Planning Pepartment and Manager of the Construction and Contracts Department. He was a visiting scholar at University of California, Berkeley (1978) in the department of Civil Engineering. He was also a member of the American Concrete Institute and the Brazilian Concrete Institute from 1978 to 1990, acting in the Committee of Concrete Technology and Concrete Construction. Mr. Saad was the president of the São Paulo Division of the Brazilian Commission on Large Dams during the period of 1994 to 1997. Mr. Saad is currently the Vice President of Generation of CPFL Geração, among other of our subsidiaries. He is also Chairman of the Board of Directors of ENERCAN, Foz do Chapecó and CERAN, and a member of the Board of Directors of BAESA, CPFL Jaguariúna, CPFL Paulista and CPFL Piratininga, among other of our subsidiaries. Mr. Saad has been our Vice President of Generation since August 28, 2002.

Paulo Cezar Coelho Tavares – Mr. Tavares graduated in Electric Engineering from Federal University of Pernambuco – UFPE, State of Recife, and received a Masters Degree in Power Systems from University of Campinas, State of São Paulo (1998). He has an MBA in finance from IBMEC, Rio de Janeiro (1998). Mr. Tavares has worked at CHESF as an engineer and as Manager of Energy Planning and Energy Commercialization. In addition, he was an Assistant to the Executive Management Team of Eletrobras, in charge of the Programa Nacional de Conservação de Energia (PROCEL) and of the Areas of Rural and Urban Distribution. He also acted as Deputy Secretary of PROCEL. Mr. Tavares coordinated several agreements and international cooperation projects related to Electricity Efficiency Area, with institutions such as the World Bank, USAID, ACEEE, CIDA, in Canada, ETSU, in the UK and ALURE, in the European Community. He was also a member of the Board of Directors of Companhia Energética de Alagoas – CEAL, Companhia Energética do Rio Grande do Norte – COSERN and Companhia Energética de Pernambuco – CELPE. He was Vice President of Corporate Development and President of CELPE, the distributor of electricity in the State of Pernambuco, and, subsequently, CEO of GCS, an energy and gas trading company of the Guaraniana Group. He is currently the Commercial Officer of CPFL Paulista, CPFL Geração, CPFL Piratininga, CPFL Brasil, Clion Assessoria e Commercialização de Energia Elétrica Ltda., CPFL Santa Cruz, CPFL Jaguariúna, RGE, and a member of the Board of Directors of CERAN and Foz do Chapecó. He is also a member of the Board of Directors at the Brazilian Association of Energy Traders (ABRACEEL). Mr. Tavares has been our Vice President of Energy Management since August 28, 2002.

Reni Antonio da Silva – Mr. Silva received a degree in Electric Engineering from the Federal University of Juiz de Fora-UFJF, State of Minas Gerais, in 1974 and a business specialization degree from the Instituto Superior de Administração (ISAD) of the Catholic University, City of Curitiba, State of Paraná, in 1997, a joint program with the business school of the University of Texas, Austin. He participated in several specialization programs, such as Management of Distribution Companies at EDF, France, and Competition in a Global World at the business school of the University of Texas. He was a trainee in several energy distribution companies in France, Italy, England, Belgium and Portugal. Mr. Silva participated in the Conselho do Mercado Atacadista de Energia – COMAE. He was also an Executive Officer of Espírito Santo Centrais Elétricas – Escelsa, an electric power company in the Brazilian State of Espírito Santo, and Empresa Energética do Mato Grosso do Sul – ENERSUL, an electric power company based in the Brazilian State of Mato Grosso do Sul, from 1998 to 2001, Supervising Commercial Manager of COPEL, an electric power company in the Brazilian State of Paraná, from 1996 to 1998; member of the Núcleo Executivo da Câmara de Gestão da Crise de Energia Elétrica – GCE; member of the Executive Committee of MAE (COEX); and member of the Board of Directors of the ONS. Mr. Silva is currently the Strategy and Regulation Executive Officer of CPFL Paulista, CPFL Piratininga, CPFL Geração, CPFL Brasil, CPFL Santa Cruz, CPFL Jaguariúna and RGE, among other of our subsidiaries. He has been our Vice President of Strategy and Regulation since August 28, 2002. He is a member of the Board of Directors of ENERCAN, among other of our subsidiaries.

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José Marcos Chaves de Melo – Mr. Melo received a degree as an Electronics Technician from CEFET in Rio de Janeiro in 1980 and a B.S. degree in Mechanical Egineering from the University of Kansas in 1986. Mr. Melo received a Fulbright Scholarship, and is a member of the U.S. National Engineering Honor Society (Tau Beta Pi). Mr. Melo worked at Accenture do Brasil from 1987 through 2008 in various capacities, including as a director from 1998 through 2008. He was responsible for sales, client development, and project supervision and execution, drawing on his twelve years of experience in the electric energy sector, five years of experience in the oil and gas sector, two years of experience in the metallurgy sector, and one year of experience in manufacturing. He also has experience in a variety of areas such as Information Tecnology, Supply Chain, Fieldwork and Asset Management. During his career, Mr. Melo has worked with CPFL, Neoenergia, Light, CEMIG, CEMAR, Celesc, Furnas, Duke, CCEE, ONS, Petrobras Gás e Energia, Petrobrás, Repsol-YPF and CSN. He is currently the Administrative Vice President of CPFL Paulista, CPFL Piratininga, CPFL Brasil and CPFL Geração, among other of our subsidiaries. He is a member of the Board of Directors of CPFL Jaguariúna, among other of our subsidiaries. He has been our Administrative Vice President since April 2008.

Fiscal Council

Under Brazilian Corporate Law, the Conselho Fiscal, or fiscal council, is a corporate body independent of the management and the company’s external auditors. Our fiscal council is permanent, although Brazilian Corporate Law allows fiscal councils to be either permanent or non-permanent and may be composed of a minimum of three and a maximum of five members. The primary responsibility of the fiscal council is to review management’s activities and the company’s financial statements, and to report its findings to the company’s shareholders. Brazilian Corporate Law requires fiscal council members to receive as remuneration at least 10% of the average annual amount paid to the company’s executive officers, excluding benefits and profit sharing. Minority holders of common shares owning in aggregate at least 10% of the common shares outstanding may also elect one member of the fiscal council.

Under Brazilian Corporate Law, our fiscal council may not include members who are on our Board of Directors, are on the board of executive officers, are employed by us or a controlled company or a company of the same group, or are spouses or relatives of any member of our management or Board of Directors. Our fiscal council elected at our shareholders meeting held on April 9, 2008, with a mandate of one year, is composed of five members: Pedro Carlos de Mello, Francisco Djalma de Oliveira, Paulo Midena, Fernando Dias Gomes and Martin Roberto Glogowsky.

In accordance with the listed company audit committee rules of the NYSE and the SEC, on June 8, 2005 our Board of Directors designated and empowered our fiscal council to perform the role of the audit committee in reliance on the exemption set forth in Exchange Act Rule 10A-3(c)(3).

Advisory Committees

In September 2006, a new model of corporate governance was approved by the Board of Directors in order to improve its corporate governance structure. The seven advisory committees (Corporate Governance Committee, Executive Committee, Processes Evaluation and Internal Controls Committee, Compensation Committee, Construction Committee, Financial Services Committee and Purchase and Sale of Raw Materials Committee) were dissolved and their responsibilities were distributed to the three new permanent advisory committees (Management Processes Committee, Human Resources Management Committee and Related Parties Committee). The committees do not have decision-making authority, and their recommendations are not binding upon the Board of Directors, but the chairperson of each committee reports on activities at the Board’s monthly meetings.

Management Processes Committee. Our Management Processes Committee is responsible for evaluating the overall management, risk profile and internal controls of the company and our subsidiaries and affiliates. The members of this committee are Otávio Carneiro de Rezende, Ricardo Carvalho Giambroni and Martin Roberto Glogowsky.

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Human Resources Management Committee. Our Human Resources Management Committee is responsible for coordinating executive personnel decisions, setting executive compensation levels and evaluating the overall performance of our executive officers. In addition, this committee determines general human resources policies for the company. The members of this committee are Cecília Mendes Garcez Siqueira, Francisco Caprino Neto and Carlos Alberto Cardoso Moreira.

Related Parties Committee. Our Related Parties Committee is responsible for monitoring and analyzing the business relationships that we have with related parties, including those that exist through supply and services contracts. The members of this committee are Daniela Corci Cardoso, Arthur Prado Silva and Humberto Pires Grault Vianna de Lima.

In addition to the advisory committees, our Board of Directors has also created six ad hoc commissions (Corporate Governance Commission, Strategy Commission, Budget Commission, Financial Services Commission, Energy Acquisition Commission and Project Commission).

Strategy Commission. Our Strategy Commission is responsible for assisting the Board of Directors with evaluating and improving our business strategy in order to meet our growth targets and long-term objectives.

Financial Services Commission. Our Financial Activities Commission is responsible for ensuring compliance and efficiency in our existing financial practices, as well as evaluating new opportunities for financial transactions that could benefit the company.

Corporate Governance Commission. Our Corporate Governance Commission is responsible for monitoring the implementation of our new corporate governance model and for suggesting potential improvements to the Board.

Budget Commission. Our Budget Commission is responsible for advising the Board of Directors on analyzing and setting our annual and long-term budgets.

Energy Acquisition Commission. Our Energy Acquisition Commission is responsible for advising the Board of Directors on analyzing the acquisition of energy originated from alternative and competitive sources by the subsidiaries of commercialization.

Project Commission. Our Project Commission is responsible for assisting the Board of Directors with evaluating new opportunities for power generation projects.

Compensation

Under Brazilian Corporate Law, our shareholders are responsible for establishing the aggregate amount we pay to the members of our Board of Directors and our executive officers. Once our shareholders establish an aggregate amount of compensation for our Board of Directors and executive officers, the Human Resources Management Committee of our Board of Directors is then responsible for setting individual compensation levels.

For the year ended December 31, 2007, the aggregate compensation, including cash and benefits-in-kind, that we paid to the members of our Board of Directors and our executive officers was approximately R$14.4 million. For the same period, the total amount set aside or accrued by the company to provide pension, retirement or similar benefits was approximately R$778,000.

Share Ownership

The total number of common shares owned by our directors and executive officers as of March 31, 2008 was 19,676. None of our directors or executive officers beneficially owns one percent or more of our common shares.

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Indemnification of Officers and Directors

Neither the laws of Brazil nor our bylaws provide for indemnification of directors or officers. We have held directors’ and officers’ liability insurance since February 2006.

Employees

As of December 31, 2007, we had 7,176 full time employees (including the employees of our jointly-controlled subsidiaries). The following table sets forth the number of our employees and a breakdown of employees by category of activity as of the dates indicated in each area of our operations.

		As of December 31,
		2007		2006		2005
Distribution		5,958		4,790		4,661
Generation		250		226		195
Commercialization		256		183		177
Corporate staff		712		637		805
Total		7,176		5,836		5,838

A majority of our employees are members of unions, with which we have collective bargaining agreements. We renegotiate these agreements annually with the ten principal unions that represent our various employee groups. Salary increases are generally provided for on an annual basis. We believe that we have good relationships with our unions as evidenced by the fact that we have not had any labor strikes during the last fifteen years.

We provide a number of benefits to our employees. The most significant is the sponsorship of Fundação CESP, in partnership with ten other electrical companies, which supplements the Brazilian government retirement and health benefits available to the employees of our subsidiaries CPFL Paulista, CPFL Piratininga, CPFL Geração and CPFL Brasil.

In accordance with Brazilian law and our compensation policy, our employees are eligible for our profit sharing program. Our Board of Directors and the shareholders must approve the amount of such compensation, which is determined in consultation with an employee committee. Funds are allocated to the employee profit sharing fund on an annual basis once we have achieved at least 80% of our projected profits for the year. In addition, we develop productivity and performance goals in conjunction with the unions. Achievement of these goals must reach at least 70% in order for the program to be fully funded. In 2007, we reserved R$28.7 million for our employee profit sharing program.

In addition, part of each employee’s compensation is linked to performance goals. Employees are evaluated based on criteria such as quality of work product, adherence to safety protocols and productivity. Our performance evaluation system is designed to evaluate required skill as well, and enables us to evaluate the development of our employees.

ITEM 7. MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS

Major Shareholders

The following table sets forth information relating to the beneficial ownership of our common shares by our major shareholders (beneficial owners of 5% or more of our common shares) as of December 31, 2007. Percentages in the following table are based on 479,910,938 outstanding common shares.

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		Common Shares		(%)
521 Participações S.A. (1)		149,233,727		31.10
VBC Energia S.A. (2)		136,329,808		28.41
Bonaire Participações S.A. (3)		60,713,511		12.65
Bradespar S.A. (4)		43,049,000		8.97
BNDES Participações S.A. (5)		27,465,653		5.72
Executive officers and directors as a group		34,076		0.01
Total		416,825,775		86.86

Shareholders’ Agreement

Voting Rights. Our shareholders’ agreement, among VBC, 521, Bonaire and us, as intervening and consenting party, governs control of CPFL and our subsidiaries. Under the shareholders’ agreement, certain actions require the approval of at least VBC and 521 (at least 80% of the shares subject to the shareholders’ agreement), including:

• election of the CEO and removal of any executive officer (including the CEO);

• definition of the dividend policy;

• creation and dissolution of controlled companies;

• acquisition and sale of investments in other entities;

• approval of our budget;

• approval of our business plan;

• capital increase within our pre-approved authorized capital and determination of the issuance price of shares;

• incurrence of indebtedness – including guarantees and collaterals in favor of controlled entities and invested companies – beyond the thresholds established in our budget or our business plan;

• execution of any agreement with a global amount in excess of R$20 million, if not included in our annual budget;

• granting of any kind of collateral or guarantee in favor of third parties;

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• execution of agreements with related parties in an amount in excess of R$5 million;

• appointment of our independent auditors in certain specified cases;

• authorization for the acquisition of our own shares for cancellation or for treasury;

• amendment of concession agreements of any controlled entity;

• approval of stock option plans; and

• acquisition, sale or encumbrance of any fixed assets in an amount equal or over R$20 million.

The terms of our shareholders’ agreement relating to voting rights apply to our controlled companies and, to the fullest extent possible, to our investee companies.

Corporate Governance. Our Board of Directors consists of seven members, appointed as follows:

• three appointed by VBC;

• two appointed by 521;

• one appointed by Bonaire; and

• one independent, in accordance with the listing regulations of the Novo Mercado. Our Fiscal Council consists of five members, appointed as follows:

• two appointed by VBC;

• two appointed by 521; and

• one appointed by Bonaire.

The number of members of the Board of Directors and the Fiscal Council nominated by each party to the shareholders’ agreement is related to the current stakes of the parties in the controlling shareholder block. If a change in the stakes of any party in the enjoined shares occurs, the number of members for which such party has the right to nominate shall be adapted to reflect such modification so as to maintain unchanged the number of members nominated by the parties whose stakes relative to the total of enjoined shares have not been altered.

If the minority shareholders, exercising their rights under the corporate law, elect the independent director required by the Bovespa’s Novo Mercado Regulations, VBC, 521 and BONAIRE must abstain from proposing a nominee for the position. If the minority shareholders do not elect the independent director, VBC, 521 and BONAIRE shall by joint accord nominate such an independent director.

The shareholders’ agreement also establishes the framework of the Board of Directors and Board of Executive Officers of our subsidiaries. According to the agreement, the executive officers of the Company must be part of the Board of Directors of our subsidiaries.

Transfer of Shares. Our shareholders’ agreement provides for certain rights and obligations in the event of transfer of shares subject to the shareholders’ agreement, or subject shares, including:

• Right of First Refusal. The parties to the shareholders agreement have a right of first refusal to acquire subject shares in the event one of them decides to sell its shares to a third party.

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• Tag-along Rights. A party that decides not to exercise its right of first refusal has the option to sell (pro rata), together with the selling party, its subject shares to the acquiring third party. Tag-along provisions do not apply to the disposition of subject shares by Bonaire while its stake within the controlling block is lower than 20%.

• Preemptive Rights. The parties have pro rata preemptive rights to subscribe for shares in the event of a capital increase.

• Tag-along Rights of Bonaire. In the event of a sale, assignment or transfer of subject shares by 521 and VBC that results in an equity percentage lower than 20% and 30%, respectively, of the aggregate subject shares and, as long as Bonaire has not exercised its right of first refusal, it will have the right to sell its entire stake of subject shares together with 521 or VBC, under the same terms and conditions.

Change of Control. In the event of direct or indirect change of control of any of the parties subject to the shareholders’ agreement, the remaining parties shall have the right to acquire all subject shares held, directly or indirectly, by the party undergoing the change of control, paying for such shares an amount to be determined by a recognized financial institution.

Option Agreement

Our controlling shareholders are also party to an agreement pursuant to which they have granted to each other options to purchase their respective shares in us. In addition, this agreement provides for (1) certain notification requirements for secondary offerings of shares by such shareholders and (2) priority to certain shareholders in the sale of shares in a secondary offering, if more than one shareholder participates in the offering and demand is less than the size of the offering.

Related Party Transactions

One of our principal shareholders is VBC, which is a joint venture of two major Brazilian groups:

• Votorantim Group, which engages in several businesses, including pulp and paper, aluminum, nickel and long steel, among others; and

• Camargo Corrêa Group, which is one of the largest privately-held industrial conglomerates in Brazil, with controlling equity interests in leading Brazilian engineering and construction, cement, footwear, and textiles companies. Camargo Corrêa also shares equity control of important Brazilian steel and highway concession companies, and it has equity participations in a significant Brazilian financial conglomerate and in a global aluminum company.

We acquired our interest in Semesa from VBC in December 2001 for R$496 million. The Semesa acquisition price is subject to adjustment, based on the assessment of Semesa’s Assured Energy. According to MME, the earliest that this assessment will take place is 2015.

We also conduct transactions with the shareholders of VBC and their affiliates, including the following:

• Our distribution subsidiaries CPFL Paulista and CPFL Piratininga have entered into agreements for the supply of electricity with several entities affiliated to VBC. All of these electricity supply agreements are regulated by ANEEL.

• Our commercialization subsidiary CPFL Brasil has entered into agreements for the supply of electricity with several entities affiliated with VBC.

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• CPFL Geração, through its subsidiaries BAESA, ENERCAN, CERAN and Foz do Chapecó, has entered into transactions with Construção e Comércio Camargo Corrêa S.A., a member of the Camargo Corrêa Group, for the provision and financing of construction services to our generation subsidiaries.

Our subsidiaries CPFL Paulista, CPFL Piratininga and CPFL Geração are sponsors of a pension fund administered by Fundação CESP, a pension fund services company that has an indirect ownership interest in one of our shareholders, Bonaire.

ITEM 8. FINANCIAL INFORMATION

Consolidated Statements and Other Financial Information

See Item “Financial Statements.”

Legal Proceedings

CPFL Paulista and CPFL Piratininga are parties to numerous lawsuits brought by industrial consumers alleging that certain tariff increases in the past were illegal in view of then prevailing economic regulations that had established a price freeze that included electricity tariffs. The aggregate potential liability was approximately R$71 million as of December 31, 2007. Superior courts have already decided many of these lawsuits partially against us, and as a result, we have provisioned the aggregate potential liability (approximately R$15.9 million) in respect of these suits.

CPFL Paulista is party to an administrative proceeding before the Brazilian Antitrust Authority (Conselho Administrativo de Defesa Econômica, or CADE), where an investigation is being conducted into alleged anticompetitive behavior in connection with the installation of CPFL Paulista’s electric grid. A judicial decision has postponed this proceeding since CPFL Paulista presented a proposal to enter into a settlement agreement (termo de cessação). Based on the opinion of external counsel, we consider the possibility of loss in this proceeding to be remote and, therefore, we have not made a provision in our financial statements in connection with this proceeding.

We are also subject to legal proceedings relating to the authorization of certain of our hydroelectric plants, including a class action proposed by the federal public attorney’s office of the Municipality of Caxias do Sul challenging the validity of the environmental licensing of the Rio das Antas Hydroelectric Complex, and requesting injunctive relief against the construction of these plants. The federal public attorney’s injunction request was denied in the lower courts and the district attorney moved against the denial, requesting a new injunction from the higher courts. The higher courts denied the injunction relief. No decision on the merits has been taken by the lower courts to date. We believe that the possibility of a loss is remote.

Semesa and Furnas were named defendents in a legal proceeding that sought remedial measures and the establishment of a nature reserve because of alleged harm caused by the construction and operation of the Serra da Mesa plant. The amount sought from Semesa totaled R$74 million. CPFL Geração assumed all of the outstanding obligations and potential liabilities of Semesa in March 2007. We believe that the risk of an adverse judgment with respect to this claim is possible. We have not established a provision with regard to this claim. If adverse judgment were entered against us, requiring us to purchase additional land and establish a preserve in the area surrounding our generation activities, the costs would be reflected in our property, plant and equipment.

CPFL Paulista is involved in a lawsuit challenging the deductibility of expenses recognized in 1997 related to a deficit from Fundação CESP’s pension fund. Based on a favorable opinion that we received from the Brazilian Internal Revenue Office, CPFL Paulista deducted those expenses for purposes of income tax payments. In 2007, we made a judicial deposit in the amount of R$360 million, which allows CPFL Paulista to proceed with the lawsuit without running the risk of any asset seizure by the tax authority. We believe that the possibility of a loss is remote.

We establish reserves in our balance sheets relating to potential losses from litigation based on estimates of such losses. For this purpose, we classify such losses as remote, possible or probable. Brazilian Accounting Principles and Brazilian law require us to establish reserves in connection with probable losses and therefore, it is our policy to establish reserves only in connection with those claims. As of December 31, 2007, our reserves for contingencies were approximately R$276.1 million. Our management believes that these proceedings will not have a material adverse effect on our financial condition, either individually or in the aggregate. See Note 20 to our audited consolidated financial statements for more information on the status of our litigation.

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Dividend Policy

For our policy on dividend distributions, see “Item 10. Additional Information—Allocation of Net Income and Distribution of Dividends.”

Significant Changes

None.

ITEM 9. THE OFFER AND LISTING

Trading Markets

Our common shares are listed on the BOVESPA, and our ADSs are listed on the New York Stock Exchange. Each ADS represents three shares.

Price Information

The table below sets forth reported high and low closing sale prices in reais per common share for the periods indicated. The table also sets forth prices in U.S. dollars per ADS based on information available from the New York Stock Exchange. See Item 3 “Key Information— Exchange Rates” for information with respect to exchange rates applicable during the periods indicated below.

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		reais per  Common Share				U.S. dollars per  ADS
		High		Low		High		Low
2004:
Fourth Quarter		17.96		14.40		20.00		15.70
2005:
Fourth Quarter		28.00		21.80		38.03		27.99
2006:
First Quarter		33.30		27.40		47.40		35.84
Second Quarter		34.21		25.15		50.50		33.89
Third Quarter		29.13		26.69		40.18		36.46
Fourth Quarter		30.50		27.00		42.39		37.90
2007:
First Quarter		31.40		27.80		45.65		38.70
Second Quarter		39.30		29.01		61.69		42.75
Third Quarter		40.44		31.03		65.87		45.78
October		38.65		34.90		66.52		58.03
November		38.90		33.43		67.28		55.12
December		37.21		33.33		64.08		56.03
2008
January		34.80		29.75		59.66		51.68
February		37.69		31.00		68.26		52.63
March		38.81		35.00		70.27		60.88
April		40.00		37.50		71.94		64.61

Corporate Governance Practices

In 2000, the BOVESPA introduced three special listing segments, known as Level 1, Level 2 and the Novo Mercado, aiming at fostering a secondary market for securities issued by Brazilian companies with securities listed on the BOVESPA, by prompting such companies to follow good practices of corporate governance. The listing segments were designed for the trading of shares issued by companies voluntarily undertaking to abide by corporate governance practices and disclosure requirements in addition to those already imposed by Brazilian law. These rules generally increase shareholders’ rights and enhance the quality of information provided to shareholders and stakeholders.

In order to maintain high standards of corporate governance, we have signed an agreement with the BOVESPA to list our securities on the Novo Mercado.

In accordance with Section 303A.11 of the NYSE Listed Company Manual, we have posted a summary of significant differences between the NYSE corporate governance standards and our corporate governance practices on our website, at http://www.cpfl.com.br/ir.

ITEM 10. ADDITIONAL INFORMATION

Memorandum and Articles of Incorporation

Corporate Purpose

Our corporate purpose, as defined by our bylaws, includes:

• developing enterprises in the electricity generation, distribution, commercialization and transmission industries;

• providing services in the electricity, telecommunications and data transmission industries, as well as provide technical, operating, administrative and financial support services, especially to affiliated or subsidiary companies; and

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• holding interest in the capital of other companies engaged in activities similar to those that we perform.

Qualification of Directors

Brazilian law provides that only shareholders of a company may be appointed to its board of directors, but there is no minimum share ownership or residency requirement for qualification as a director. Members of our board of executive officers must be Brazilian nationals and resident in Brazil. Our directors and executive officers are prevented from voting on any transaction involving companies in which they hold more than 10% of the total capital stock or of which they have held a management position in the period immediately prior to their taking office.

Allocation of Net Income and Distribution of Dividends

The discussion below summarizes the provisions of Brazilian law regarding the establishment of reserves by corporations and the distribution of dividends, including interest attributed to shareholders’ equity.

Mandatory Distribution

Brazilian Corporate Law generally requires that the bylaws of each Brazilian corporation specify a minimum percentage of the amounts available for distribution by such corporation for each fiscal year that must be distributed to shareholders as dividends, also known as the mandatory distribution.

The mandatory distribution is based on a percentage of adjusted net income, not lower than 25%, rather than a fixed monetary amount per share. Under our bylaws, at least 25% of our adjusted net income, as calculated under Brazilian Accounting Principles and adjusted under Brazilian Corporate Law, for the preceding fiscal year must be distributed as a mandatory annual dividend. Adjusted net income means the distributable amount before any deductions for statutory reserves and reserves for investment projects.

Brazilian Corporate Law permits the suspension of the mandatory distribution of dividends in any fiscal year in which the management bodies report to the shareholders’ meeting that the distribution would be inadvisable in view of the company’s financial condition. The suspension is subject to approval by the shareholders meeting and review by members of the fiscal council. The law does not establish the circumstances in which payment of the mandatory dividend would be “inadvisable” based on the company’s financial condition. In the case of publicly held corporations, the board of directors must file a justification for such suspension with the CVM within five days of the relevant general meeting. If the mandatory distribution is not paid, the unpaid amount must be attributed to a special reserve account. If not absorbed by subsequent losses, those funds must be paid out as dividends as soon as the financial condition of the company permits. Under Brazilian Corporate Law, the shareholders of a publicly-held company may also decide to distribute dividends in an amount lower than the mandatory distribution.

Payment of Dividends

We are required by Brazilian Corporate Law to hold an annual general shareholders’ meeting by no later than April 30 of each year, at which the shareholders have to decide on the payment of an annual dividend. Additionally, interim dividends may be declared by our Board of Directors. Pursuant to our charter, we are required to pay a mandatory annual dividend of at least 25% of our adjusted net income. Any holder of record of shares at the time of a dividend declaration is entitled to receive dividends. Dividends on shares held through a depositary are paid to the depositary for further distribution to the shareholders. Under Brazilian Corporate Law, dividends are generally required to be paid to the holder of record on a dividend declaration date within 60 days following the date the dividend was declared, unless a shareholders’ resolution sets forth another date of payment, which, in either case, must occur prior to the end of the fiscal year in which such dividend was declared. Pursuant to our bylaws, unclaimed dividends do not bear interest, are not monetarily adjusted and revert to us three years after the date when we begin to pay such declared dividends.

In general, shareholders who are not residents of Brazil must register their equity investment with the Central Bank to have dividends, sales proceeds or other amounts with respect to their shares eligible to be remitted outside of Brazil. The common shares underlying the ADSs are held in Brazil by Banco Bradesco S.A., as the custodian for the depositary, that is the registered owner on the records of the registrar for our shares. The current registrar is Banco Bradesco S.A. The depositary registers the common shares underlying the ADSs with the Central Bank and, therefore, is able to have dividends, sales proceeds or other amounts with respect to the common shares remitted outside Brazil.

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Payments of cash dividends and distributions, if any, are made in reais to the custodian on behalf of the depositary, which then converts such proceeds into U.S. dollars for distribution to holders of ADSs. In the event that the custodian is unable to convert immediately the Brazilian currency received as dividends into U.S. dollars, the amount of U.S. dollars payable to holders of ADSs may be adversely affected by depreciations of the Brazilian currency that occur before the dividends are converted. Dividends paid to persons who are not Brazilian residents, including holders of ADSs, are not subject to Brazilian withholding tax, except for dividends declared based on profits generated prior to December 31, 1995, which are subject to Brazilian withholding income tax at varying tax rates. See “Taxation—Brazilian Tax Considerations.”

Holders of ADSs have the benefit of the electronic registration obtained from the Central Bank, which permits the depositary and the custodian to convert dividends and other distributions or sales proceeds with respect to the common shares represented by ADSs into foreign currency and remits the proceeds outside of Brazil. In the event the holder exchanges the ADSs for common shares, the holder will be entitled to continue to rely on the depositary’s certificate of registration for five business days after the exchange. Thereafter, in order to convert foreign currency and remit outside Brazil the sales proceeds or distributions with respect to the common shares, the holder must obtain a new certificate of registration in its own name that will permit the conversion and remittance of such payments through the foreign exchange market.

If the holder is not a duly qualified investor and does not obtain an electronic certificate of foreign capital registration, a special authorization from the Central Bank must be obtained in order to remit from Brazil any payments with respect to the common shares through the foreign exchange market. Without this special authorization, the holder may currently remit payments with respect to the common shares through the floating rate exchange market, although no assurance can be given that the floating rate exchange market will be accessible for these purposes in the future.

In addition, a holder who is not a duly qualified investor and who has not obtained an electronic certificate of foreign capital registration or a special authorization from the Central Bank may remit these payments by international transfer of Brazilian currency pursuant to CMN Resolution No. 3,265, dated March 4, 2005, and Central Bank Circular No. 3,280, dated March 9, 2005, as amended. In order to effect the international transfer of Brazilian currency the holder must have a special non-resident bank account in Brazil, through which the subsequent conversion of such Brazilian currency into U.S. dollars is effected.

Under current Brazilian legislation, the Brazilian government may impose temporary restrictions of foreign capital abroad in the event of a serious imbalance or an anticipated serious imbalance of Brazil’s balance of payments (see “Item 3. Key Information—Risk Factors—Risks Relating to the ADSs and Our Common Shares.”)

Interest Attributable to Shareholders’ Equity

Under Brazilian tax legislation, Brazilian companies are permitted to pay “interest” to holders of equity securities and treat such payments as an expense for Brazilian income tax purposes and for social contribution purposes. Payment of such interest may be made at the discretion of our Board of Directors, subject to the approval of the shareholders at a general shareholders’ meeting. In order to calculate this interest on shareholders’ equity, the TJLP is applied to shareholders’ equity for the applicable period. The amount of any such notional “interest” payment to holders of equity securities is generally limited in respect of any particular year to the greater of:

• 50% of net income (after the deduction of the provisions for social contribution on net profits but before taking into account the provision for corporate income tax and the interest attributable to shareholders’ equity) for the period in respect of which the payment is made; or

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• 50% of the sum of retained earnings and profit reserves as of the beginning of the year in respect of which such payment is made.

For accounting purposes, although the interest charge must be reflected in the statement of operations to be tax-deductible, the charge is reversed before calculating net income in the statutory financial statements and deducted from shareholders’ equity in a manner similar to a dividend. Any payment of interest in respect of common shares (including the holders of the ADSs) is subject to Brazilian withholding tax at the rate of 15%, or 25% in the case of a shareholder domiciled in a tax haven. See “Taxation—Brazilian Tax Considerations.” If such payments are accounted for, at their net value, as part of any mandatory dividend, the tax is paid by the company on behalf of its shareholders, upon distribution of the interest. If we distribute interest attributed to shareholder’s equity in any year, and that distribution is not accounted for as part of mandatory distribution, Brazilian income tax would be borne by the shareholders.

Under our bylaws, interest attributable to shareholders’ equity may be treated as a dividend for purposes of the mandatory dividend.

The dividend for 2007 was R$1,561.3 million, of which R$842.4 million, or R$1.75584 per common share, was paid on September 28, 2007 and R$718.9 million is scheduled to be paid on April 30, 2008.

Dividend Policy

We intend to declare and pay dividends and/or interest attributed to shareholders’ equity in amounts equivalent to 50% of our adjusted net income. The amount of any of our distributions of dividends and/or interest attributed to shareholders’ equity will depend on a series of factors, such as our financial conditions, prospects, macroeconomic conditions, tariff adjustments, regulatory changes, growth strategies and other matters our Board of Directors and our shareholders may consider relevant. In addition, covenants contained in our debt instruments may limit the amount of dividends and/or interest attributable to shareholders’ equity that we may make. Within the context of our tax planning, we may in the future determine that it is to our benefit to distribute interest attributable to shareholders’ equity in lieu of dividends.

Our Board of Directors may approve the distribution of dividends and/or interest attributed to shareholders’ equity, calculated based on our annual or semi-annual financial statements or on financial statements relating to shorter periods, or also based on accrued profits recorded or on profits allocated to non-profits reserve accounts in the annual or semi-annual financial statements. The declaration of annual dividends, including dividends in excess of the mandatory distribution, requires approval by the vote of the majority of the holders of our common shares.

Shareholder Meetings

Actions to be taken at our shareholders’ meetings

At our shareholder meetings, shareholders are generally empowered to take any action relating to our corporate purpose and to pass such resolutions as they deem necessary. The approval of our financial statements and the determination of the allocation of our net profits with respect to each fiscal year takes place at the annual shareholder meeting immediately following such fiscal year. The election of our directors and members of our fiscal council — if the requisite shareholders request its establishment — typically takes place at the annual shareholders’ meeting, although under Brazilian law it may also occur at a special shareholders’ meeting.

A special shareholders’ meeting may be held concurrently with the annual shareholders’ meeting. The following actions may only be taken at a special shareholders’ meeting:

• amendment of our bylaws;

• cancellation of registration with the CVM as a publicly-held company;

• authorization of the issuance of debentures;

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• suspension of the rights of a shareholder who has violated Brazilian Corporate Law or our bylaws;

• acceptance or rejection of the valuation of in-kind contributions offered by a shareholder in consideration for shares of our capital stock;

• approval of our transformation into a limited liability company (sociedade limitada) or any other corporate form;

• delisting of our common shares from the Novo Mercado;

• appointment of a financial institution responsible for our valuation, in the event that a tender offer for our common shares is carried out in connection with a corporate transformation or delisting of our common shares from the Novo Mercado;

• approval of any merger (fusão) or consolidation (incorporação) with another company or a spin-off (cisão);

• approval of any dissolution or liquidation, the appointment and dismissal of the respective liquidator and the official review of the reports prepared by him or her;

• authorization to petition for bankruptcy or judicial or extrajudicial restructuring (recuperação judicial or extrajudicial); and

• approval of stock option plans to managers or employees of the Company and its subsidiaries.

According to Brazilian Corporate Law, neither a company’s bylaws nor actions taken at a shareholders’ meeting may deprive a shareholder of some specific rights, such as:

• the right to participate in the distribution of profits;

• the right to participate equally and ratably in any remaining residual assets in the event of liquidation of the company;

• the right to preemptive rights in the event of subscription of shares, convertible debentures or subscription warrants (bônus de subscrição), except in some specific circumstances under Brazilian law described in “—Preemptive rights;” and

• the right to withdraw from the company in the cases specified in Brazilian Corporate Law, described in “—Withdrawal rights.”

Quorum

As a general rule, Brazilian Corporate Law provides that a quorum at a shareholders’ meeting consists of shareholders representing at least 25% of a company’s issued and outstanding voting capital on the first call and, if that quorum is not reached, any percentage on the second call. A quorum for the purposes of amending our bylaws consists of shareholders representing at least two-thirds of our issued and outstanding voting capital on the first call and any percentage on the second call.

As a general rule, the affirmative vote of shareholders representing at least the majority of our issued and outstanding common shares present in person or represented by proxy at a shareholders’ meeting is required to ratify any proposed action, with abstentions not taken into account. However, the affirmative vote of shareholders representing one-half of our issued and outstanding voting capital is required to:

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• reduce the percentage of mandatory dividends;

• change our corporate purpose;

• merge us with another company, if we are not the surviving company, or of our consolidation with another company;

• spin off a portion of our assets or liabilities;

• approve our participation in a group of companies (as defined in Brazilian Corporate Law);

• apply for cancellation of any voluntary liquidation; and

• approve our dissolution.

According to our bylaws and for so long as we are listed on the Novo Mercado, we may not issue preferred shares or founders’ shares and, to delist ourselves from the Novo Mercado, we will have to conduct a tender offer.

Notice of our Shareholders’ Meetings

Notice of our shareholders’ meetings must be published at least three times in the Diário Oficial do Estado de São Paulo, the official newspaper of the State of São Paulo, and in the newspaper Valor Econômico. The first notice must be published no later than 15 days before the date of the meeting on the first call, and no later than eight days before the date of the meeting on the second call. However, in certain circumstances, the CVM may require that the first notice be published 30 days in advance of the meeting.

Location of our Shareholders’ Meetings

Our shareholders’ meetings take place at our head offices in the city of São Paulo, State of São Paulo. Brazilian Corporate Law allows our shareholders to hold meetings outside our head offices in the event of force majeure, provided that the meetings are held in the City of São Paulo and the relevant notice contains a clear indication of the place where the meeting will occur.

Who May Call our Shareholders’ Meetings

In addition to our Board of Directors, shareholders’ meetings may also be called by:

• any shareholder, if our directors fail to call a shareholders’ meeting within 60 days after the date they were required to do so under applicable laws and our bylaws;

• shareholders holding at least five percent of our capital stock, if our directors fail to call a meeting within eight days after receipt of a request to call the meeting by those shareholders indicating the proposed agenda; and

• our fiscal council, if one is in place, if the Board of Directors delays calling an annual shareholders’ meeting for more than one month. The fiscal council may also call a special shareholders’ meeting any time if it believes that there are important or urgent matters to be addressed.

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Conditions of Admission

Shareholders attending our shareholders’ meeting must provide their identification cards and produce proof of ownership of the shares they intend to vote.

A shareholder may be represented at a shareholders’ meeting by a proxy, as long as the proxy is appointed less than a year before the shareholders’ meeting. The proxy must be a shareholder, an officer of the corporation, a lawyer or a financial institution. An investment fund must be represented by its investment fund officer. A proxy must deposit with the company proof of its appointment at least 24 hours before our shareholders’ meetings.

Voting Rights of ADS Holders

ADS holders may instruct the depositary to vote the number of common shares that their ADSs represent. The depositary will notify those holders of shareholders’ meetings and arrange to deliver our voting materials to them upon our request. Those materials will describe the matters to be voted on and explain how the ADS holders may instruct the depositary how to vote. For instructions to be valid, they must reach the depositary by a date set by the depositary.

We cannot assure ADS holders that they will receive the voting materials or otherwise learn of an upcoming shareholders’ meeting in time to ensure that they can instruct the depositary to vote their common shares. In addition, the depositary and its agents are not responsible for failing to carry out voting instructions or for the manner of carrying out voting instructions. This means that ADS holders may not be able to exercise their right to vote and there may be nothing that they can do if their shares are not voted as they requested.

Preemptive Rights

Our shareholders have a general preemptive right to subscribe for shares in any capital increase according to the proportion of their shareholdings. Our shareholders also have a general preemptive right to subscribe for any convertible debentures, rights to acquire our shares and subscription warrants that we may issue. In accordance with our bylaws, a period of at least 30 days, in the case of a private placement, and 10 days, in the case of a public offering, following the publication of notice of the capital increase is allowed for the exercise of the preemptive right. Under Brazilian Corporate Law, holders are permitted to transfer or dispose of their preemptive right for consideration.

In addition, Brazilian Corporate Law allows for companies’ bylaws to give the board of directors the power to exclude preemptive rights or reduce the exercise period of such rights with respect to the issuance of new shares, debentures convertible into shares and subscription warrants up to the limit of the authorized share capital if the distribution of those shares is effected through a stock exchange, through a public offering or through an exchange of shares in a public offering the purpose of which is to acquire control of another company. Our bylaws currently have no such provision.

Withdrawal Rights

Brazilian Corporate Law grants our shareholders the right to withdraw from the company in case they disagree with decisions taken in shareholder’s meetings concerning the following matters: (i) the reduction of mandatory dividends; (ii) the merger of the company; (iii) the change of the corporate purpose of the company; or (iv) a spinoff of the company (if such spin-off changes the company’s corporate purpose, reduces mandatory dividends or results in the company joining a group of entities). Even shareholders who did not vote or were not present at the relevant meeting may exercise this withdrawal right.

If our shareholders wish to withdraw from the company due to a merger, such right may only be exercised provided that the company’s shares have no liquidity in the market.

The withdrawal right entitles the shareholder to the reimbursement of the value of its shares, upon request within 30 days of the publication of notice of the shareholders meeting. After such term, the company’s management bodies may choose to call a general meeting to ratify or reconsider the decision which triggered the withdrawal rights, should the payment of such rights threaten the financial stability of the company.

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Material Contracts

For information concerning our material contracts, see “Item 4. Information on the Company” and “Item 5. Operating and Financial Review and Prospects.”

Exchange Controls and Other Limitations Affecting Security Holders

There are no restrictions on ownership of our capital stock by individuals or legal entities domiciled outside Brazil. However, the right to convert dividend payments and proceeds from the sale of common shares into foreign currency and to remit such amounts outside Brazil is subject to restrictions under foreign investment legislation which generally requires, among other things, that the relevant investment be registered with the Central Bank. These restrictions on the remittance of foreign capital abroad could hinder or prevent the custodian for the common shares represented by American Depositary Shares, or holders who have exchanged American Depositary Shares for common shares, from converting dividends, distributions or the proceeds from any sale of common shares into U.S. dollars and remitting such U.S. dollars abroad. Delays in, or refusal to grant any required government approval for conversions of Brazilian currency payments and remittances abroad of amounts owed to holders of American Depositary Shares could adversely affect holders of American depositary receipts.

Resolution No. 1,927/1992 of the National Monetary Council, which is the restated and amended Annex V to Resolution No. 1,289/1997, which we call the Annex V Regulations, provides for the issuance of depositary receipts in foreign markets in respect of shares of Brazilian issuers. It provides that the proceeds from the sale of American Depositary Shares by holders of American depositary receipts outside Brazil are free of Brazilian foreign investment controls and holders of American Depositary Shares who are not resident in a tax haven jurisdiction (i.e. a country or location that does not impose taxes on income or where the maximum income tax rate is lower than 20%, or where the legislation imposes restrictions on disclosure of the shareholding composition or the ownership of the investment) will be entitled to favorable tax treatment.

An electronic registration has been issued by the custodian in the name of The Bank of New York, the depositary, with respect to the American Depositary Shares. Pursuant to this electronic registration, the custodian and the depositary are able to convert dividends and other distributions with respect to the common shares represented by American Depositary Shares into foreign currency and to remit the proceeds outside Brazil. If a holder exchanges American Depositary Shares for common shares, the holder may continue to rely on the custodian’s electronic registration for only five business days after the exchange. After that, the holder must seek to obtain its own electronic registration with the Central Bank under Law No. 4,131/1962 or Resolution No. 2,689/2000. Thereafter, unless the holder has registered its investment with the Central Bank, such holder may not convert into foreign currency and remit outside Brazil the proceeds from the disposition of, or distributions with respect to, such common shares. A holder that obtains an electronic registration generally will be subject to less favorable Brazilian tax treatment than a holder of American Depositary Shares. See “—Taxation—Brazilian Tax Considerations.”

Under Brazilian law, whenever there is a serious imbalance in Brazil’s balance of payments or reasons to foresee a serious imbalance, the Brazilian government may impose temporary restrictions on the remittance to foreign investors of the proceeds of their investments in Brazil, and on the conversion of Brazilian currency into foreign currencies. Such restrictions may hinder or prevent the custodian or holders who have exchanged American Depositary Shares for underlying common shares from converting distributions or the proceeds from any sale of such shares, as the case may be, into U.S. dollars and remitting such U.S. dollars abroad.

Taxation

The following summary contains a description of the material Brazilian and U.S. federal income tax consequences of the acquisition, ownership and disposition of common shares or ADSs, but it does not purport to be a comprehensive description of all the tax considerations that may be relevant to a decision to purchase common shares or ADSs. The summary is based upon the tax laws of Brazil and regulations thereunder and on the tax laws of the United States and regulations thereunder as in effect on the date hereof, which are subject to change. Holders of common shares or ADSs should consult their own tax advisors as to the tax consequences of the acquisition, ownership and disposition of common shares or ADSs.

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Although there is at present no income tax treaty between Brazil and the United States, the tax authorities of the two countries have had discussions that may culminate in such a treaty. No assurance can be given, however, as to whether or when a treaty will enter into force or how it will affect the U.S. holders of common shares or ADSs. Prospective holders of common shares or ADSs should consult their own tax advisors as to the tax consequences of the acquisition, ownership and disposition of common shares or ADSs in their particular circumstances.

Brazilian Tax Considerations

The following discussion summarizes the material Brazilian tax consequences of the acquisition, ownership and disposition of our common shares or ADSs by a holder that is not domiciled in Brazil for purposes of Brazilian taxation, or a Non-Brazilian Holder.

Pursuant to Brazilian law, foreign investors may invest in the common shares under Resolution No. 2,689 of the National Monetary Council, or Resolution No. 2,689.

Resolution No. 2,689 allows foreign investors to invest in almost all financial assets and to engage in almost all transactions available in the Brazilian financial and capital markets, provided that some requirements are fulfilled. In accordance with Resolution No. 2,689, the definition of foreign investor includes individuals, legal entities, mutual funds and other collective investment entities, domiciled or headquartered abroad.

Pursuant to Resolution No. 2,689, foreign investors must: (a) appoint at least one representative in Brazil with powers to perform actions relating to the foreign investment; (b) complete the appropriate foreign investor registration form; (c) register as a foreign investor with the CVM; and (d) register the foreign investment with the Central Bank.

Securities and other financial assets held by foreign investors pursuant to Resolution No. 2,689 must be registered or maintained in deposit accounts or under the custody of an entity duly licensed by the Central Bank or the CVM. In addition, securities trading is restricted to transactions carried out in the stock exchanges or organized over-the-counter markets licensed by the CVM, except for transfers resulting from a corporate reorganization, occurring upon the death of an investor by operation of law or will or as a consequence of the delisting of the relevant shares from a stock exchange and the cancellation of the registration with the CVM.

Taxation of Dividends

Dividends, including dividends in kind, paid by us to the depositary in respect of the common shares underlying the ADSs or to a Non-Brazilian Holder in respect of common shares generally will not be subject to Brazilian withholding income tax provided that they are paid out of profits generated as of or after January 1, 1996. Dividends relating to profits generated prior to December 31, 1995 are subject to Brazilian withholding tax from 15% to 25% according to the tax legislation applicable to each corresponding year in which the profits have been earned.

Taxation of Gains

ADSs. According to applicable Brazilian law (Law No. 10,833/2003), capital gains arising from transactions between two non-resident parties, involving assets situated in Brazil, are subject to Brazilian withholding income tax, at a rate of 15% (25% in case the seller is situated in a tax haven jurisdiction). Arguably, the gains realized by a Non-Brazilian Holder on the disposition of ADSs to another non-Brazilian resident should not be taxed in Brazil, based on the idea that ADSs would not constitute assets located in Brazil for purposes of Law No. 10,833/2003. However, we cannot assure you of how Brazilian courts would interpret the definition of assets located in Brazil in connection with the taxation of gains realized by a Non- Brazilian Holder on the disposition of ADSs to another non-Brazilian resident. Thus, the gain on a disposition of ADSs by a Non-Brazilian Holder to a resident in Brazil (or possibly to a Non-Brazilian Holder), in the event that courts determine that ADSs constitute assets located in Brazil, may be subject to income tax in Brazil according to the rules described below for the common shares. Non-Brazilian Holders should consult their own tax advisor concerning the tax consequences of a sale of ADSs in Brazil.

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Although there are grounds to sustain otherwise, the deposit of common shares in exchange for ADSs may be subject to Brazilian withholding tax, if the acquisition cost of the common shares is lower than (a) the average price per common share on a Brazilian stock exchange on which the greatest number of such shares were sold on the day of deposit; or (b) if no common shares were sold on that day, the average price on the Brazilian stock exchange on which the greatest number of common shares were sold in the 15 trading sessions immediately preceding such deposit. In such case, the difference between the acquisition cost and the average price of the common shares calculated as above will be considered to be a capital gain subject to income tax at a rate of 15% or 25% in the case of investors located in a tax haven jurisdiction (unless if the common shares were held by an investor registered under Resolution 2,689 that is not resident in a tax haven jurisdiction, which is currently tax exempt from income tax in such transaction).

The withdrawal of common shares upon cancellation of ADSs is not subject to Brazilian income tax, as long as the regulatory rules are appropriately observed with respect to the registration of the investment before the Central Bank.

Common Shares. As a general rule, gains realized by Non-Brazilian Holders on any disposition of common shares are subject to income tax at a rate of 15%, regardless of whether the sale or the disposition is made by the Non-Brazilian Holder to a resident or non-resident in Brasil, or if the transaction is conducted in Brazil or abroad, except for the specific cases described below.

Gains realized on any disposition of common shares by Non-Brazilian Holders who are resident in a jurisdiction that is deemed to be a “tax haven jurisdiction” under Brazilian law (i.e., a country that does not impose any income tax or that imposes tax at a maximum rate of less than 20%, or which laws impose restrictions on disclosure of ownership composition or securities ownership) are subject to income tax at a rate of 25%.

Gains realized on sales or disposition of common shares carried out on the Brazilian stock exchange by Non-Brazilian Holders who are not resident in a tax haven jurisdiction are exempt from income tax, if such Non-Brazilian Holder is registered under Resolution 2,689. If the Non-Brazilian Holder is a resident of a tax haven or is not registered under Resolution 2,689, the gain realized on such sale or disposition of common shares is subject to income tax at a rate of 15%. In these cases, a withholding income tax of 0.005% on the sale value shall be applicable and can be offset with the eventual income tax due on the capital gain.

Gains on the disposition of common shares are measured by the difference between the amount in Brazilian currency obtained from the sale or exchange of the shares and their acquisition cost in Brazilian currency, without any monetary adjustment. However, for Non-Brazilian Holders with a direct investment in common shares registered as foreign capital with the Central Bank of Brazil, the acquisition cost should be measured in foreign currency, converted into reais at the date of the sale.

Exercise of Preemptive Rights. Any exercise of preemptive rights relating to the common shares or ADSs will not be subject to Brazilian taxation. Any gain on the sale or assignment of preemptive rights relating to common shares by the depositary on behalf of holders of ADSs will be subject to Brazilian income taxation according to the same rules applicable to the sale or disposition of common shares.

Interest Attributable to Shareholders’ Equity. Payments of interest on shareholders’ equity to shareholders who are either Brazilian residents or non-Brazilian residents, including holders of ADSs, are subject to Brazilian income withholding tax at the rate of 15%, or 25% for shareholders domiciled in a tax haven jurisdiction. If such payments are accounted for, at their net value, as part of any mandatory dividend, the tax is paid by the company on behalf of its shareholders, upon payment of the interest. If we pay interest on shareholders’ equity in any year, and that payment is not accounted for as part of a mandatory dividend distribution, Brazilian income tax would be borne by the shareholders.

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The payment of interest on shareholders’ equity may be recommended by our Board of Directors and needs to be approved by our general shareholders’ meeting. We cannot assure you that our Board of Directors will not recommend that future distributions of profits may be made by means of interest on shareholders’ equity instead of by means of dividends.

Tax on foreign exchange transactions

The conversion of foreign currency into Brazilian reais as well as the conversion of Brazilian reais into foreign currency are subject to a tax on foreign exchange transactions (“IOF/Exchange”). The Brazilian government has recently announced tax changes to reduce the loss of revenue from the expiration of the CPMF, increasing the applicable rates to the IOF/Exchange Tax. The rate of such tax varies according to the nature of the transaction, as follows:

• Inflow and outflow of funds from Non-Brazilian residents registered under Resolution 2,689 for investment in variable-yield securities on the Brazilian stock exchange or the commodities and futures exchange, except those transactions with derivatives that result in predetermined income: 0%;

• Inflow of funds from foreign investors for the acquisition of shares in an Initial Public Offering or subscription of shares of a company registered on the Brazilian stock exchange in a private transaction: 0%;

• Remittances of dividends and interest on equity to foreign investors related to the abovementioned transactions: 0%;

• Inflow of funds from foreign investors for investment in the financial and capital markets (except those mentioned above): 1.5%;

• Outflow of funds related to the abovementioned transactions performed by foreign investors (except private transactions involving shares): 0%;

• Other foreign exchange transactions, except those with a maturity term of of 90 days or less: 0.38% .

The IOF/Exchange may be changed at any time, up to 25%, upon the discretion of the President. Any such increase, although immediately applicable, would only apply to future transactions.

Tax on transactions involving bonds and securities

Brazilian law imposes a tax on transactions involving bonds and securities (the “IOF/Bonds Tax”), including those carried out on Brazilian stock, futures or commodities exchanges. However, this rate may be increased at any time to up to 1.5% per day by the President, but only with respect to future transactions. Currently, this tax is reduced to zero on all transactions involving stocks.

Other Relevant Brazilian Taxes

There are no Brazilian inheritance, gift or succession taxes applicable to the ownership, transfer or disposition of common shares or ADSs by a Non-Brazilian Holder except for gift and inheritance taxes levied by certain Brazilian states on gifts or inheritance bestowed by individuals or entities not resident or domiciled in Brazil or not domiciled within that state, to individuals or entities resident or domiciled within in that Brazilian state. There are no Brazilian stamp, issue, registration or similar taxes or duties payable by holders of common shares or ADSs.

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U.S. Federal Income Tax Consequences

The statements regarding U.S. tax law set forth below are based on U.S. law as in force on the date of this prospectus, and changes to such law subsequent to the date of this annual report may affect the tax consequences described herein. This summary describes the material tax consequences of the ownership and disposition of common shares or ADSs, but it does not purport to be a comprehensive description of all of the tax consequences that may be relevant to a decision to hold or dispose of common shares or ADSs, including tax considerations that arise from rules of general application to all taxpayers or to certain classes of investors or that are generally assumed to be known by investors. This summary applies only to holders of common shares or ADSs who hold the common shares or ADSs as capital assets and does not apply to special classes of holders such as dealers in securities or currencies, holders whose functional currency is not the U.S. dollar, holders of 10% or more of our shares (taking into account shares held directly or through depositary arrangements), tax-exempt organizations, financial institutions, holders liable for the alternative minimum tax, securities traders who elect to account for their investment in common shares or ADSs on a mark-to-market basis, partnerships or other pass-through entities, insurance companies, U.S. expatriates, and persons holding common shares or ADSs in a hedging transaction or as part of a straddle or conversion transaction.

Each holder should consult such holder’s own tax advisor concerning the overall tax consequences to it, including the consequences under laws other than U.S. federal income tax laws, of an investment in common shares or ADSs.

In this discussion, references to ADSs also refer to common shares (unless stated otherwise), and references to a “U.S. holder” are to a holder of an ADS (1) that is an individual who is a citizen or resident of the United States of America, (2) that is a corporation, or any other entity taxable as a corporation, organized under the laws of the United States of America or any state thereof, including the District of Columbia, or (3) that is otherwise subject to U.S. federal income taxation on a net basis with respect to the ADSs.

For purposes of the U.S. Internal Revenue Code of 1986, as amended, or the Code, holders of ADSs will be treated as owners of the common shares represented by such ADSs.

Taxation of Distributions. A U.S. holder will recognize ordinary dividend income for U.S. federal income tax purposes in an amount equal to the amount of any cash and the value of any property distributed by us as a dividend, when such distribution is received by the custodian (or by the U.S. holder in the case of a holder of common shares). The amount of any distribution will include the amount of Brazilian tax withheld on the amount distributed, and the amount of a distribution paid in reais will be measured by reference to the exchange rate for converting reais into U.S. dollars in effect on the date the distribution is received by the custodian (or by a U.S. holder in the case of a holder of common shares). If the custodian (or U.S. holder in the case of a holder of common shares) does not convert such reais into U.S. dollars on the date it receives them, it is possible that the U.S. holder will recognize foreign currency loss or gain, which would be ordinary loss or gain, when the reais are converted into U.S. dollars. Dividends paid by us will not be eligible for the dividends received deduction allowed to corporations under the Code.

Subject to certain exceptions for short-term and hedged positions, the U.S. dollar amount of dividends received by an individual prior to January 1, 2011 with respect to the ADSs will be subject to taxation at a maximum rate of 15% if the dividends are “qualified dividends.” Dividends paid on the ADSs will be treated as qualified dividends if (i) the ADSs are readily tradable on an established securities market in the United States and (ii) the Company was not, in the year prior to the year in which the dividend was paid, and is not, in the year in which the dividend is paid, a passive foreign investment company (“PFIC”). The ADSs are listed on the New York Stock Exchange, and will qualify as readily tradable on an established securities market in the United States so long as they are so listed. Based on our audited financial statements and relevant market and shareholder data, we believe that we were not treated as a PFIC for U.S. federal income tax purposes with respect to our 2007 taxable year. In addition, based on our audited financial statements and current expectations regarding the value and nature of our assets, the sources and nature of our income, and relevant market and shareholder data, we do not anticipate becoming a PFIC for our 2008 taxable year.

Based on existing guidance, it is not entirely clear whether dividends received with respect to the common shares will be treated as qualified dividends, because the common shares are not themselves listed on a U.S. exchange. In addition, the U.S. Treasury has announced its intention to promulgate rules pursuant to which holders of ADSs or common shares and intermediaries through whom such securities are held will be permitted to rely on certifications from issuers to establish that dividends are treated as qualified dividends. Because such procedures have not yet been issued, it is not clear whether we will be able to comply with them. Holders of ADSs and common shares should consult their own tax advisers regarding the availability of the reduced dividend tax rate in the light of their own particular circumstances.

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Distributions out of earnings and profits with respect to the ADSs generally will be treated as dividend income from sources outside of the United States and generally will be treated separately along with other items of “passive” income for purposes of determining the credit for foreign income taxes allowed under the Code. Subject to certain limitations, Brazilian income tax withheld in connection with any distribution with respect to the ADSs may be claimed as a credit against the U.S. federal income tax liability of a U.S. holder if such U.S. holder elects for that year to credit all foreign income taxes. Alternatively such Brazilian withholding tax may be taken as a deduction against taxable income if the U.S. holder does not take a credit for any foreign income tax during the taxable year. Foreign tax credits will not be allowed for withholding taxes imposed in respect of certain short-term or hedged positions in securities and may not be allowed in respect of certain arrangements in which a U.S. holder’s expected economic profit is insubstantial. U.S. holders should consult their own tax advisors concerning the implications of these rules in light of their particular circumstances.

Distributions of additional shares to holders with respect to their ADSs that are made as part of a pro rata distribution to all our shareholders generally will not be subject to U.S. federal income tax.

Holders of ADSs that are foreign corporations or nonresident alien individuals, which we call “non-U.S. holders,” generally will not be subject to U.S. federal income tax or withholding tax on distributions with respect to ADSs that are treated as dividend income for U.S. federal income tax purposes unless such dividends are effectively connected with the conduct by such holders of a trade or business in the United States.

Taxation of Capital Gains. Upon the sale or other disposition of an ADS, a U.S. holder will generally recognize gain or loss for U.S. federal income tax purposes. The amount of the gain or loss will be equal to the difference between the amount realized in consideration for the disposition of the ADS (including the gross amount of the proceeds before the deduction of any Brazilian tax) and the U.S. holder’s tax basis in the ADS. Such gain or loss generally will be subject to U.S. federal income tax and will be treated as capital gain or loss and will be long-term capital gain or loss if the ADS has been held for more than one year. The net amount of long-term capital gain recognized by an individual holder is taxed at a reduced rate. Capital losses may be deducted from taxable income, subject to certain limitations. Gain realized by a U.S. holder on a sale or disposition of ADSs generally will be treated as U.S. source income. Consequently, if Brazilian tax is imposed on such gain, the U.S. holder will not be able to use the corresponding foreign tax credit, unless the holder has other foreign source income of the appropriate type in respect of which the credit may be used. Alternatively such Brazilian tax may be taken as a deduction against taxable income if the U.S. holder does not take a credit for any foreign income tax during the taxable year.

A non-U.S. holder will not be subject to U.S. federal income tax or withholding tax on gain realized on the sale or other disposition of an ADS unless (1) such gain is effectively connected with the conduct by the holder of a trade or business in the United States, or (2) such holder is an individual who is present in the United States of America for 183 days or more in the taxable year of the sale and certain other conditions are met.

Backup Withholding and Information Reporting

Dividends paid on, and proceeds from the sale or other disposition of, the ADSs to a U.S. holder generally may be subject to the information reporting requirements of the Code and may be subject to backup withholding unless the U.S. holder provides an accurate taxpayer identification number or otherwise establishes an exemption. The amount of any backup withholding collected from a payment to a U.S. holder will be allowed as a credit against the U.S. holder’s U.S. federal income tax liability and may entitle the U.S. holder to a refund, provided that certain required information is furnished to the Internal Revenue Service.

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A non-U.S. holder generally will be exempt from these information reporting requirements and backup withholding tax, but may be required to comply with certain certification and identification procedures in order to establish its eligibility for such exemption.

Documents on Display

Statements contained in this annual report regarding the contents of any contract or other document are not necessarily complete, and, where the contract or other document is an exhibit to the annual report, each of these statements is qualified in all respects by the provisions of the actual contract or other documents.

We are subject to the information requirements of the Securities Exchange Act of 1934, as amended, applicable to a foreign private issuer, and accordingly, we file or furnish reports, information statements and other information with the SEC. Reports and other information filed by us with the SEC can be inspected at, and subject to the payment of any required fees, copies may be obtained from, the public reference facilities of the SEC, 100 F Street, N.E., Washington, D.C. 20549. Our filings will also be available at the SEC’s website at http://www.sec.gov.

Reports and other information may also be inspected and copied at the offices of the New York Stock Exchange, 20 Broad Street, New York, New York 10005. As a foreign private issuer, however, we are exempt from the proxy requirements of Section 14 of the Exchange Act and from the short-swing profit recovery rules of Section 16 of the Exchange Act.

Our website is located at http://www.cpfl.com.br and our investor relations website is located at http://www.cpfl.com.br/ir. (These URLs are intended to be an inactive textual reference only. They are not intended to be an active hyperlink to our website. The information on our website, which might be accessible through a hyperlink resulting from this URL, is not and shall not be deemed to be, incorporated into this Annual Report.)

ITEM 11. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to market risk from changes in both foreign currency exchange rates and rates of interest and indexation. We have foreign exchange rate risk with respect to our debt denominated in U.S. dollars. We are subject to market risk deriving from changes in rates which affect the cost of our financing.

Exchange Rate Risk

At December 31, 2007, we had outstanding approximately R$1,085.0 million of indebtedness denominated in foreign currencies, including U.S. dollars and Japanese yen, and R$102.2 million of indebtedness denominated in Brazilian reais, but partially indexed to the U.S. dollar. Also at December 31, 2007, we had swap agreements that offset the exchange rate risk with respect to R$1,031.6 million of those amounts. The potential loss to us that would result from a hypothetical unfavorable 10% change in foreign currency exchange rates, after giving effect to the swaps, would be approximately R$15.6 million, primarily due to the increase in real terms in the principal amount of our foreign currency indebtedness. The total increase in our foreign currency indebtedness would be reflected as an expense in our income statement.

Risk of Index Variation

We have indebtedness and financial assets that are denominated in reais and that bear interest at variable rates or, in some cases, are indexed. We also have swaps that convert some U.S.-dollar denominated indebtedness to reais at variable interest rates. The interest or indexation rates include several different Brazilian money-market rates and inflation rates. At December 31, 2007, the amount of such liabilities, net of such assets and after giving effect to swaps, was R$5,147.9 million.

A hypothetical, instantaneous and unfavorable change of 100 basis points in rates applicable to floating rate financial assets and liabilities held at December 31, 2007, would result in a net additional cash outflow of approximately R$51.5 million. This sensitivity analysis is based on the assumption of an unfavorable 100 basis point movement of the interest rates applicable to each homogeneous category of financial assets and liabilities. A homogeneous category is defined according to the currency in which financial assets and liabilities are denominated and assumes the same interest rate movement within each homogeneous category (e.g., U.S. dollars). As a result, our interest rate risk sensitivity model may overstate the impact of interest rate fluctuations for such financial instruments as consistently unfavorable movements of all interest rates are unlikely.

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ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES

Not Applicable.

ITEM 13. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES

None.

ITEM 14. MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS

None.

ITEM 15. CONTROLS AND PROCEDURES

We have evaluated, with the participation of our chief executive officer and chief financial officer, the effectiveness of our disclosure controls and procedures as of December 31, 2007. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon our evaluation, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the applicable rules and forms, and that it is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate to allow timely decisions regarding required disclosure.

Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Our 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. Our internal control over financial reporting includes those policies and procedures that: (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect our transactions and dispositions of our assets; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of our assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of the effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, and that the degree of compliance with the policies or procedures may deteriorate.

Our management has assessed the effectiveness of our internal control over financial reporting as of December 31, 2007 based on the criteria established in “Internal Control - Integrated Framework” issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Based on such assessment and criteria, our management has concluded that our internal control over financial reporting was effective as of December 31, 2007.

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The effectiveness of our internal control over financial reporting as of December 31, 2007 has been audited by KPMG Auditores Independentes, an independent registered public accounting firm, as stated in their report that appears herein.

There has been no change in our internal control over financial reporting during 2007 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Report of Independent Registered Public Accounting Firm, On Internal Control Over Financial Reporting

To the Board of Directors and Shareholders of CPFL Energia S.A.

We have audited CPFL Energia S.A.’s internal control over financial reporting as of December 31, 2007, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). CPFL Energia S.A.’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Form 20-F. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company's 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. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, CPFL Energia S.A. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2007, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of CPFL Energia S.A. and subsidiaries as of December 31, 2007, and the related consolidated statements of income, changes in shareholders’ equity, and changes in financial position for the year then ended, and our report dated on April 2, 2008 except for note 34, which is as of April 18, 2008, expressed an unqualified opinion on those consolidated financial statements.

/s/ KPMG Auditores Independentes
KPMG Auditores Independentes
Campinas, Brazil
April 2, 2008, except for note 34, which is as of April 18, 2008

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ITEM 16A. AUDIT COMMITTEE FINANCIAL EXPERT

As described in Item 16D below, we have given our fiscal council the necessary powers to qualify for the exemption from the audit committee requirements set forth in Exchange Act Rule 10A-3(c)(3). Our Board of Directors recognizes that two members of our fiscal council, Pedro Carlos de Mello and Paulo Midena, individually qualify as audit committee financial experts and meet the applicable independence requirements for fiscal council membership under Brazilian law. They also meet the New York Stock Exchange independence requirements that would apply to audit committee members in the absence of our reliance on the exemption set forth in Exchange Act Rule 10A-3(c)(3). Some of the members of our fiscal council are currently employed by some of our principal shareholders or their affiliates.

ITEM 16B. CODE OF ETHICS

We have adopted a Code of Ethics applicable to our employees and our directors and executive officers, which addresses such matters as conflicts of interest, corporate opportunities, confidentiality, fair dealing, protection and proper use of company assets, compliance with laws, rules and regulations (including insider trading laws) and encouraging the reporting of any illegal or unethical behavior. Our Code of Ethics is available on our website at: http://www.b2i.cc/Document/986/CPFL_CodEtica_20061227_eng.pdf. (This URL is intended to be an inactive textual reference only. It is not intended to be an active hyperlink to our website. The information on our website, which might be accessible through a hyperlink resulting from this URL, is not and shall not be deemed to be, incorporated into this Annual Report). If we amend the provisions of our code of ethics that apply to our chief executive officer, our chief financial officer, our principal accounting officer and persons performing similar functions, or if we furnish a waiver to any such persons, we will disclose such amendment or waiver on our website at the same address.

ITEM 16C. PRINCIPAL ACCOUNTANT FEES AND SERVICES

Audit and Non-Audit Fees

The following table sets forth the fees billed to us by our independent registered and public accounting firm during the years ended December 31, 2007 and 2006. Our independent accounting firm was Deloitte Touche Tohmatsu Auditores Independentes through the 2006 audit and KPMG Auditores Independentes beginning in 2007.

		Year ended December 31,
		2007		2006
		(in thousands of reais)
Audit fees		R$2,172		R$3,849
Audit-related fees		75		271
Tax fees		88		53
All other fees		-		0
Total		R$2,335		R$4,173

“Audit Fees” are the aggregated fees billed by KPMG Auditores Independentes and Deloitte Touche Tohmatsu Auditores Independentes for the audit of our consolidated and annual financial statements, reviews of interim financial statements and attestation services that are provided in connection with statutory and regulatory filings or engagements for the fiscal years of 2007 and 2006, respectively. Audit fees in the above table are for services rendered by our principal accountant for the integrated audit of our financial statements, including additional services rendered in 2006 and 2007 for compliance with the Sarbanes-Oxley Act.

“Audit-related fees” are fees charged by KPMG Auditores Independentes and Deloitte Touche Tohmatsu Auditores Independentes for assurance and related services that are reasonably related to the performance of the audit or review of our financial statements.

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“Tax fees” in the above table are for services related to tax compliance.

Audit Committee Approval Policies and Procedures

Our fiscal council currently serves as our audit committee for purposes of the Sarbanes-Oxley Act of 2002. Our fiscal council has not established pre-approval policies or procedures for recommending the engagement of our independent auditors for services to our Board of Directors. Pursuant to Brazilian law, our Board of Directors is responsible for the engagement of independent auditors. Brazilian law prohibits our independent auditors from providing any consulting services to our subsidiaries, or to us, that may impair their independence.

ITEM 16D. EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES

Under the listed company audit committee rules of the NYSE and the SEC, we must comply with Exchange Act Rule 10A-3, which requires that we establish an audit committee composed of members of the Board of Directors that meets specified requirements. We have designated and empowered our fiscal council to perform the role of the audit committee in reliance on the exemption set forth in Exchange Act Rule 10A-3(c)(3). In our assessment, our fiscal council acts independently in performing the responsibilities of an audit committee under the Sarbanes-Oxley Act and satisfies the other requirements of Exchange Act Rule 10A-3.

ITEM 16E. PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS

None.

ITEM 17. FINANCIAL STATEMENTS

Not applicable.

ITEM 18. FINANCIAL STATEMENTS

See pages F-1 through F-95, incorporated herein by reference.

ITEM 19. EXHIBITS

No.		Description
1.1		Amended and Restated Bylaws of CPFL Energia S.A. (together with an English version).
8.1		List of subsidiaries, their jurisdiction of incorporation and names under which they do business.
10.1		Shareholders Agreement dated March 22, 2002 as amended on August 27, 2002, November 5, 2003 and December 6, 2007, among VBC Energia S.A., 521 Participações S.A., Bonaire Participações S.A. and CPFL Energia S.A.
12.1		Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
12.2		Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
13.1		Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
13.2		Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
The amount of long-term debt securities of CPFL Energia or its subsidiaries authorized under any outstanding agreement does not exceed 10% of CPFL Energia’s total assets on a consolidated basis. CPFL Energia hereby agrees to furnish the SEC, upon its request, a copy of any instruments defining the rights of holders of its long-term debt or of its subsidiaries for which consolidated or unconsolidated financial statements are required to be filed.

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GLOSSARY OF TERMS

ABRADEE: Brazilian Association of Electric Energy Distributors (Associação Brasileira de Distribuidores de Energia Elétrica).

ANEEL: National Electric Energy Agency (Agência Nacional de Energia Elétrica).

Assured Energy: Amount of energy that generators are allowed to sell in long-term contracts.

Basic Network: Interconnected transmission lines, dams, energy transformers and equipment with voltage equal to or higher than 230 kV, or installations with lower voltage as determined by ANEEL.

CCC: Fuel Usage Quota.

CCEE: Energy Trading Chamber (Câmara de Comercialização de Energia Elétrica). The short-term electricity market, established in 1998 through the Power Industry Law, which replaced the prior system of regulated generation prices and supply contracts, formerly known as the Wholesale Energy Market.

CNPE: National Energy Policy Council (Conselho Nacional de Política Energética).

Distribution Network: Electric network system that distributes energy to end customers within a concession area. Distributor: An entity supplying electric energy to a group of customers by means of a distribution network. Final customer: A party that uses electricity for its own needs.

Free consumers: (i) Existing customers with demand of at least 10 MW and supplied at voltage level equal to or greater than 69 kV; (ii) new customers with demand of at least 3 MW at any voltage; (iii) groups of customers subject to agreement with the local distribution concessionaire; (iv) customers who do not receive supply for more than 180 days from a local distribution concessionaire; and (v) certain others.

GCE: Energy Crisis Management Chamber (Câmara de Gestão da Crise de Energia Elétrica).

Gigawatt (GW): One billion watts.

Gigawatt hour (GWh): One gigawatt of power supplied or demanded for one hour, or one billion watt hours.

High voltage: A class of nominal system voltages equal to or greater than 100,000 volts (100 kVs) and less than 230,000 volts (230 kVs).

Hydroelectric plant or hydroelectric facility: A generator that uses water power to drive the electric generator.

Initial Supply Contracts: Initial energy supply agreements at prices and volumes approved by ANEEL, that distribution and generation companies are required to enter into per the 1998 Power Industry Law.

Installed capacity: The level of electricity which can be delivered from a particular generator on a full-load continuous basis under specified conditions as designated by the manufacturer.

Interconnected Power System: Systems or networks for the transmission of energy, connected together by means of one or more links (lines and/or transformers).

Independent Power Producer: a legal entity or consortium holding a concession or authorization for power generation for sale for its own account to public utility concessionaires or Unregulated Customers.

Itaipu: Itaipu Binacional, a hydroelectric facility owned equally by Brazil and Paraguay.

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Kilovolt (kV): One thousand volts.

Kilowatt (kW): One thousand watts.

Kilowatt hour (kWh): One kilowatt of power supplied or demanded for one hour, or one thousand watt hours. Megawatt (MW): One million watts. Megawatt hour (MWh): One megawatt of power supplied or demanded for one hour, or one million watt hours.

MME: Ministry of Mines and Energy (Ministério de Minas e Energia).

MRE: Energy Reallocation Mechanism.

ONS: National System Operator (Operador Nacional do Sistema), an entity responsible for operational planning, administration of generation and transmission and planning of transmission investments in the power industry.

Parcel A costs: Costs that include, among others, the following:

• costs of electricity purchased for resale pursuant to Initial Supply Contracts;

• costs of electricity purchased from Itaipu;

• costs of electricity purchased pursuant to bilateral agreements that are freely negotiated between parties; and

• certain other charges for the transmission and distribution systems.

Rationing Program: The Brazilian government program to reduce electricity consumption that was in effect from June 1, 2001 to February 28, 2002 as a result of poor hydrological conditions that threatened the country’s electricity supply.

RTE: Extraordinary Tariff Adjustment (reajuste tarifário extraordinário).

Small Hydroelectric Power Plants: Power projects with capacity from 1 MW to 30 MW.

substation: An assemblage of equipment which switches and/or changes or regulates the voltage of electricity in a transmission and distribution system.

thermoelectric plant: A generator which uses combustible fuel, such as coal, oil, diesel natural gas or other hydrocarbon as the source of energy to drive the electric generator.

transmission: The bulk transfer of electricity from generating facilities to the distribution system at load center station by means of the transmission grid (in lines with capacity between 69 kV and 525 kV).

volt: The basic unit of electric force analogous to water pressure in pounds per square inch.

watt: The basic unit of electrical power.

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SIGNATURES

     Pursuant to the requirements of Section 12 of the Securities Exchange Act of 1934, the registrant, CPFL Energia S.A., hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused this annual report to be signed on its behalf by the undersigned, thereunto duly authorized, in the city of Campinas, State of São Paulo, Brazil, on April 30, 2008.

 

		CPFL ENERGIA S.A.
	By:	/s/ Wilson Ferreira Jr.
		Name: Wilson Ferreira, Jr.
		Title: Chief Executive Officer (principal executive officer)
	By:	/s/ José Antonio de Almeida Filippo
		Name: José Antonio de Almeida Filippo
		Title: Chief Financial Officer (principal financial officer)

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	KPMG Auditores Independentes	Central Tel	55 (19) 2129-8700
	Av. Barão de Itapura, 950 - 6º	Fax	55 (19) 2129-8728
	13020-431 - Campinas, SP - Brasil	Internet	www.kpmg.com.br
	Caixa Postal 737
	13012-970 - Campinas, SP - Brasil

Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders of
CPFL Energia S.A.

We have audited the accompanying consolidated balance sheet of CPFL Energia S.A. and subsidiaries (the Company) as of December 31, 2007, and the related consolidated statements of income, changes in shareholders’ equity, and changes in financial position for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of CPFL Energia S.A. and subsidiaries as of December 31, 2007, and the results of their operations, changes in shareholders’ equity and changes in financial position for the year then ended, in conformity with accounting practices adopted in Brazil.

Accounting practices adopted in Brazil vary in certain significant respects from U.S. generally accepted accounting principles. Information relating to the nature and effect of such differences is presented in Note 35 to the consolidated financial statements.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), CPFL Energia S.A. and subsidiaries internal control over financial reporting as of December 31, 2007, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated on April 2, 2008, except for note 34, which is as of April 18, 2008, expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

/s/ KPMG Auditores Independentes
KPMG Auditores Independentes

Campinas, Brazil
April 2, 2008, except for note 34, which is as of April 18, 2008

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	Deloitte Touche Tohmatsu
	Av. Dr. José Bonifácio Coutinho
	Nogueira, 150 - 5° Andar - Sala 502
	13091-611 - Campinas - SP
	Brasil
	Telefone: (19) 3707-3000
	Fac-símile: (19) 3707-3001
	www.deloitte.com.br

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of
CPFL Energia S.A.
São Paulo - SP, Brazil

We have audited the consolidated balance sheet of CPFL Energia S.A. (a Brazilian corporation) and its subsidiaries (the “Company”) as of December 31, 2006, and the related consolidated statements of operations, changes in shareholders’ equity and changes in financial position for each of the two years in the period ended December 31, 2006, all expressed in Brazilian reais. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We did not audit the financial statements of Rio Grande Energia S.A. (an indirectly owned subsidiary), which statements reflect assets constituting 14.3% of consolidated total assets as of December 31, 2006, and net revenues constituting 16.0% and 13.0%, respectively, of consolidated total net revenues for the years ended December 31, 2006 and 2005. Those financial statements were audited by other auditors whose unqualified report has been furnished to us. Our opinion, insofar as it relates to the amounts included in the consolidated financial statements for this consolidated indirectly owned subsidiary is based solely on the report of such other auditors.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits and the report of other auditors provide a reasonable basis for our opinion.

In our opinion, based on our audits and on the report of other auditors, such consolidated financial statements present fairly, in all material respects, the financial position of CPFL Energia S.A. and subsidiaries as of December 31, 2006, and the results of their operations, changes in shareholders’ equity and changes in their financial position for each of the two years in the period ended December 31, 2006, in conformity with accounting practices adopted in Brazil.

Accounting practices adopted in Brazil vary in certain significant respects from accounting principles generally accepted in the United States of America. Information relating to the nature and effect of such differences is presented in Note 35 to the consolidated financial statements.

As discussed in Note 35 to the consolidated financial statements, effective December 31, 2006, the Company, changed its method of accounting for defined benefit pension and other postretirement plans to conform to Statement of Financial Accounting Standards No. 158.

/s/ Deloitte Touche Tohmatsu Auditores Independentes
Deloitte Touche Tohmatsu Auditores Independentes

June 28, 2007

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CPFL ENERGIA S.A. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2007 AND 2006

(In thousands of Brazilian reais – R$)

ASSETS		2007		2006
CURRENT ASSETS
Cash and cash equivalents (note 4)		927,897		540,364
Financial investments (note 5)		213,450		118,501
Accounts receivable (note 6)		1,817,788		2,124,968
Allowance for doubtful accounts (note 7)		(95,639)		(99,609)
Recoverable taxes (note 8)		181,754		170,953
Materials and supplies		14,812		16,008
Deferred cost variations (note 3)		532,449		334,353
Prepaid expenses (note 9)		202,721		191,239
Derivatives (note 31)		995		-
Deferred taxes (note 10)		168,485		188,942
Other (note 11)		111,352		110,009
		4,076,064		3,695,728
NONCURRENT ASSETS
Accounts receivable (note 6)		215,014		165,183
Escrow deposits (note 20)		498,044		81,846
Financial investments (note 5)		97,521		103,901
Recoverable taxes (note 8)		99,947		103,049
Deferred cost variations (note 3)		205,894		512,678
Prepaid expenses (note 9)		43,111		28,769
Deferred taxes (note 10)		1,163,976		908,605
Other (note 11)		231,820		142,057
		2,555,327		2,046,088
PERMANENT ASSETS
Property, plant and equipment (note 12)		7,139,670		6,237,081
Special obligations (note 12)		(919,097)		(791,387)
Goodwill (note 13)		2,565,683		2,806,643
Other		178,122		54,628
		8,964,378		8,306,965
TOTAL ASSETS		15,595,769		14,048,781

The accompanying notes are an integral part of these consolidated financial statements.

F - 1

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CPFL ENERGIA S.A. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2007 AND 2006

(In thousands of Brazilian reais – R$)

LIABILITIES AND SHAREHOLDERS’ EQUITY		2007		2006
CURRENT LIABILITIES
Suppliers (note 14)		867,954		854,161
Taxes and payroll charges payable (note 15)		604,093		522,758
Dividends and interest on shareholders’ equity		743,628		732,518
Accrued interest on loans and financing (note 16)		59,135		29,859
Accrued interest on debentures (note 17)		71,524		66,178
Post-retirement benefit obligation (note 18)		64,484		86,715
Regulatory charges (note 19)		68,696		105,013
Loans and financing (note 16)		862,705		658,116
Debentures (note 17)		154,617		159,252
Accrued liabilities		43,987		53,998
Deferred gain variations (note 3)		230,038		162,350
Derivatives (note 31)		18,187		50,664
Reserve for contingencies (note 20)		765		-
Other (note 21)		427,723		303,693
		4,217,536		3,785,275
LONG -TERM LIABILITIES
Suppliers (note 14)		223		-
Accrued interest on loans and financing (note 16)		26,057		2,550
Loans and financing (note 16)		2,865,104		2,472,998
Debentures (note 17)		2,208,472		1,779,445
Post-retirement benefit obligation (note 18)		656,040		773,646
Taxes and social contribution payable (note 15)		16,529		39,741
Reserve for contingencies (note 20)		116,412		103,711
Deferred gain variations (note 3)		68,389		71,069
Derivatives (note 31)		158,552		24,094
Other (note 21)		219,492		127,941
		6,335,270		5,395,195
MINORITY INTEREST		88,129		2,034
SHAREHOLDERS’ EQUITY (note 22)
Common stock (without par value, 2007 - 479,910,938
shares issued and outstanding; 2006 - 479,756,730
shares issued and outstanding)		4,741,175		4,734,790
Capital reserves		16		16
Profit reserves		213,643		131,471
		4,954,834		4,866,277
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY		15,595,769		14,048,781

The accompanying notes are an integral part of these consolidated financial statements.

F - 2

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CPFL ENERGIA S.A. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME FOR THE YEARS

ENDED DECEMBER 31, 2007, 2006 AND 2005

(In thousands of Brazilian reais – R$, except for share and per share amounts)

		2007		2006		2005
OPERATING REVENUES (note 23)
Electricity sales to final consumers		12,355,216		10,899,280		9,841,134
Electricity sales to wholesalers		682,942		500,529		460,129
Other revenues		1,169,226		827,243		605,795
		14,207,384		12,227,052		10,907,058
DEDUCTIONS FROM OPERATING REVENUES
Contribution to concession reserve fund (RGR)		(52,250)		(42,904)		(41,029)
ICMS (state VAT)		(2,477,084)		(2,165,696)		(1,911,382)
COFINS/PIS (taxes on revenue)		(1,347,865)		(1,100,178)		(985,681)
ISS (service tax)		(1,749)		(1,209)		(901)
Fuel Consumption Account - CCC		(425,860)		(554,275)		(392,454)
Energy Development Account - CDE		(398,427)		(370,182)		(272,842)
Research and development and energy efficient		(94,565)		(77,605)		(81,341)
Emergency charges (ECE/EAEE)		(49)		(3,053)		(229,153)
		(4,797,849)		(4,315,102)		(3,914,783)
NET OPERATING REVENUES		9,409,535		7,911,950		6,992,275
OPERATING COSTS
Electricity purchased for resale (note 24)		(4,052,280)		(3,419,197)		(3,174,765)
Electricity network usage charges (note 24)		(702,781)		(774,077)		(757,186)
Personnel		(263,169)		(242,678)		(199,669)
Post-retirement benefit obligation (note 18)		46,887		7,470		(90,362)
Materials		(49,664)		(39,189)		(33,990)
Outside services		(134,045)		(111,177)		(98,030)
Depreciation and amortization		(341,492)		(297,482)		(273,154)
Services cost rendered to third parties		(6,441)		(21,394)		(11,899)
Other		(35,961)		(12,638)		(12,029)
		(5,538,946)		(4,910,362)		(4,651,084)
OPERATING EXPENSES (note 25)
Sales and marketing		(428,053)		(244,231)		(197,510)
General and administrative		(353,904)		(314,409)		(266,927)
Amortization of goodwill		(176,306)		(151,844)		(125,709)
Other		(34,423)		(19,387)		(108,445)
		(992,686)		(729,871)		(698,591)
OPERATING INCOME		2,877,903		2,271,717		1,642,600

(Continues)

F - 3

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CPFL ENERGIA S.A. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME FOR THE YEARS
ENDED DECEMBER 31, 2007, 2006 AND 2005
(In thousands of Brazilian reais – R$, except for share and per share amounts)
		Continued

		2007		2006		2005
FINANCIAL INCOME (EXPENSE) (note 26)
Financial income		493,425		597,894		604,341
Financial expense		(864,026)		(748,357)		(816,040)
		(370,601)		(150,463)		(211,699)
NONOPERATING INCOME (EXPENSE) (note 27)
Nonoperating income		6,387		73,877		10,508
Nonoperating expense		(37,034)		(24,040)		(10,868)
		(30,647)		49,837		(360)
INCOME BEFORE TAXES, EXTRAORDINARY ITEM
AND MINORITY INTEREST		2,476,655		2,171,091		1,430,541
Social contribution tax (note 10)		(232,473)		(187,818)		(92,372)
Current tax		(202,083)		(172,998)		(101,787)
Deferred tax		(30,390)		(14,820)		9,415
Income tax (note 10)		(595,552)		(546,445)		(243,961)
Current tax		(560,363)		(477,036)		(287,008)
Deferred tax		(35,189)		(69,409)		43,047
INCOME BEFORE EXTRAORDINARY ITEM AND
MINORITY INTEREST		1,648,630		1,436,828		1,094,208
Extraordinary item, net of taxes of R$ 16,729 for 2006
and 2005 (note 18)		-		(32,559)		(32,559)
Minority interest		(5,194)		(173)		(40,371)
NET INCOME		1,643,436		1,404,096		1,021,278
NUMBER OF SHARES OUTSTANDING AT
YEAR END		479,910,938		479,756,730		479,756,730
EARNINGS PER SHARE		3.424		2.927		2.129

The accompanying notes are an integral part of these consolidated financial statements.

F - 4

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CPFL ENERGIA S.A. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(In thousands of Brazilian reais – R$, except for share)

														Changes in the number of
										Retained  earnings  (Accumulated deficit)		Total  Shareholder’s  equity
		Common  Stock		Treasury  shares		Capital  Reserves		Profit  reserves						Treasury  Shares		Common  shares		Total shares
Balance as of December 31, 2004		4,082,036		-		-		13,946		(74,871)		4,021,111		-		451,628,769		451,628,769
Capital increase		652,754		-		-		-		-		652,754				28,127,961		28,127,961
Treasury shares		-		(8)		-		-				(8)		817		(817)		-
Net income		-		-		-		-		1,021,278		1,021,278		-		-		-
Allocation of income:
- Statutory reserve		-		-		-		47,320		(47,320)		-		-		-		-
- Interim dividend		-		-		-		-		(323,677)		(323,677)		-		-		-
- Interim interest on shareholder’s equity		-		-		-		-		(76,920)		(76,920)		-		-		-
- Dividend proposed		-		-		-		-		(389,195)		(389,195)		-		-		-
- Interest on shareholder’s equity		-		-		-		-		(109,295)		(109,295)		-		-		-
Balance as of December 31, 2005		4,734,790		(8)		-		61,266		-		4,796,048		817		479,755,913		479,756,730
Treasury shares		-		8		-		-		-		8		(817)		817		-
Capital reserves		-		-		16		-		-		16		-		-		-
Net income		-		-		-		-		1,404,096		1,404,096		-		-		-
Allocation of income:
- Statutory reserve		-		-		-		70,205		(70,205)		-		-		-		-
- Interim dividend		-		-		-		-		(611,981)		(611,981)		-		-		-
- Dividend proposed		-		-		-		-		(721,910)		(721,910)		-		-		-
Balance as of December 31, 2006		4,734,790		-		16		131,471		-		4,866,277		-		479,756,730		479,756,730
Capital increase		6,385		-		-		-		-		6,385		-		154,208		154,208
Net income .		-		-		-		-		1,643,436		1,643,436		-		-		-
Allocation of income:
- Statutory reserve		-		-		-		82,172		(82,172)		-		-		-		-
- Interim dividend		-		-		-		-		(842,375)		(842,375)		-		-		-
- Dividend proposed		-		-		-		-		(718,889)		(718,889)		-		-		-
Balance as of December 31, 2007		4,741,175		-		16		213,643		-		4,954,834		-		479,910,938		479,910,938

The accompanying notes are an integral part of these consolidated financial statements.

F - 5

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CPFL ENERGIA S.A. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN FINANCIAL POSITION

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(In thousands of Brazilian reais – R$)

		2007		2006		2005
SOURCES OF FUNDS
From operations:
Net income		1,643,436		1,404,096		1,021,278
Items not affecting working capital:
Provision for losses on realization of extraordinary tariff adjustment		-		-		91,805
Extraordinary tariff adjustment — monetary restatement		(19,740)		(124,952)		(243,800)
Other regulatory assets		(21,962)		415		(38,729)
Amortization of goodwill and depreciation of property, plant and equipment		548,161		474,714		427,958
Long-term monetary and exchange variations		(25,294)		(10,157)		(89,148)
Losses (gains) on changes in interest in subsidiaries		(3,909)		(62,747)		840
Gains (losses) on disposal of property, plant and equipment		28,197		17,336		(684)
Deferred taxes - Assets and liabilities		18,343		90,064		(84,685)
Post-retirement benefit obligation		(46,887)		39,597		124,853
Reserve for contingencies		11,704		(86,117)		74,494
Minority interest		5,194		173		40,371
Financial compensation — Tariff increase		-		(10,402)		(28,441)
Unrealized losses on derivatives		98,890		22,845		(15,061)
Research and Development and Energy Efficiency Programs		1,647		10,863		24,578
Other		(14,969)		(1,837)		6,004
Total from operations		2,222,811		1,763,891		1,311,633
From shareholders:
Capital contributions — in cash		1,757		-		-
Capital contributions – Subscription bonus		-		-		17,258
Conversion of treasury shares		481		-		-
		2,238		-		17,258
From third parties:
Long-term financing and debentures		1,691,582		2,080,081		544,028
Transfer from noncurrent to current assets		102,911		692,424		356,150
Special obligations		65,917		56,209		23,371
Increase in noncurrent net assets due to acquisition of subsidiary		25,074		63,653		-
Sale of permanent assets		21,456		4,618		18,261
Net transfers from noncurrent to current – CVA		354,823		144,470		162,625
Advance for future capital increase		82,597		-		-
Sale of equity interest		2,635		89,899		1,225
Other		25,271		3,882		6,288
		2,372,266		3,135,236		1,111,948
Total sources		4,597,315		4,899,127		2,440,839

(Continues)

F - 6

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CPFL ENERGIA S.A. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN FINANCIAL POSITION
FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005
(In thousands of Brazilian reais - R$)
		(Continued)

		2007		2006		2005
USES OF FUNDS
Purchase of interest in subsidiaries		418,334		627,327		6,829
Increase in property, plant and equipment		1,132,757		797,235		626,537
Transfer from long-term to current liabilities		929,274		1,705,597		1,135,464
Dividends and interest on shareholders’ equity		1,561,595		1,333,995		917,985
Advance energy purchase agreement		27,474		-		-
Transfer from current to noncurrent assets		18,921		65,058		83,889
Additions to deferred charges		33,794		12,622		7,102
Financial investments		25,717		26,996		105,254
Escrow deposits		376,505		38,171		78,704
Other		124,869		12,682		22,576
		4,649,241		4,619,683		2,984,340
INCREASE (DECREASE) IN WORKING CAPITAL		(51,925)		279,444		(543,501)
REPRESENTED BY
Current assets:
At beginning of year		3,695,728		3,770,291		3,222,665
At year end		4,076,064		3,695,728		3,770,291
		380,336		(74,563)		547,626
Current liabilities:
At beginning of year		3,785,275		4,139,282		3,048,155
At year end		4,217,536		3,785,275		4,139,282
		432,261		(354,007)		1,091,127
INCREASE (DECREASE) IN WORKING CAPITAL		(51,925)		279,444		(543,501)

The accompanying notes are an integral part of these consolidated financial statements.

F - 7

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CPFL ENERGIA S.A. AND SUBSIDIARIES

NOTES TO THE FINANCIAL STATEMENTS

(Amounts in thousands of Brazilian reais, unless otherwise indicated)

1. THE COMPANY AND ITS OPERATIONS

The Company

CPFL Energia S.A. (“CPFL Energia” or “Company”) is a public corporation organized under the laws of Brazil, formed to invest in companies engaged in the distribution, generation, and sale of electric energy.

The Company has direct and indirect interests in the following subsidiaries (information about the concession area, number of consumers, energy production capacity and related data is unaudited):

Distribution activities

Companhia Paulista de Força e Luz (“CPFL Paulista”)

CPFL Paulista is a Brazilian public company and has a concession to distribute electric energy through 2027, for 234 municipalities in the state of São Paulo, serving approximately 3.4 million consumers. Among the main municipalities are Campinas, Ribeirão Preto, Bauru and São José do Rio Preto. This concession may be extended for an additional 30 years.

Companhia Piratininga de Força e Luz (“CPFL Piratininga”)

CPFL Piratininga is a Brazilian public company and has a concession to distribute electric energy through 2028, for 27 municipalities in the state of São Paulo, serving approximately 1.3 million consumers. Among the main municipalities are Santos, Sorocaba and Jundiaí. This concession may be extended for an additional 30 years.

Rio Grande Energia S.A. (“RGE”)

RGE is a Brazilian public company that has a concession to distribute electric energy through 2027, for 262 municipalities in the northern and northeastern regions of the state of Rio Grande do Sul, serving approximately 1.2 million conumers. Among the main municipalities are Passo Fundo and Caxias do Sul. This concession may be extended for an additional 30 years.

Companhia Luz e Força Santa Cruz (“CPFL Santa Cruz”)

CPFL Santa Cruz is a private corporation and has a concession to distribute electric energy through 2015, for 24 municipalities in the state of São Paulo, in the Central-Sorocabana region, and in 3 municipalities in the north of the State of Paraná, serving approximately 169 thousand consumers. Among the main municipalities are Ourinhos, Avaré and Santa Cruz do Rio Pardo. This concession may be extended for an additional 20 years period.

Companhia Paulista de Energia Elétrica (“CPFL Leste Paulista”)

CPFL Leste Paulista is a private corporation and has a concession to distribute electric energy through 2015, for 7 municipalities in the state of São Paulo, serving approximately 48 thousand consumers. Among the main municipalities are Sao Jose do Rio Pardo and Casa Branca. This concession may be extended for an additional 20 years period.

Companhia Sul Paulista de Energia (“CPFL Sul Paulista”)

CPFL Sul Paulista is a private corporation and has a concession to distribute electric energy through 2015, for 5 municipalities in the state of São Paulo, serving approximately 66 thousand consumers. Among the main municipalities is Itapetininga. This concession may be extended for an additional 20 years period.

F - 8

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Companhia Jaguari de Energia (“CPFL Jaguari”)

CPFL Jaguari is a private corporation and has a concession to distribute electric energy through 2015, for 2 municipalities in the state of São Paulo: Jaguariúna and Pedreira, serving approximately 30 thousand consumers. This concession may be extended for an additional 20 years period.

Companhia Luz e Força Mococa (“CPFL Mococa”)

CPFL Mococa is a private corporation and has a concession to distribute electric energy through 2015, for the municipality of Mococa, in the state of São Paulo, and 3 municipalities in the state of Minas Gerais: Arceburgo, Itamogi and Monte Santo de Minas, serving approximately 38 thousand consumers. This concession may be extended for an additional 20 years period.

Generation activities

CPFL Geração de Energia S.A. (“CPFL Geração”)

CPFL Geração is a Brazilian public company, which operated until 2006 as a holding company for the Company's energy generation business. As from 2007, with the mergers of CPFL Centrais Elétricas S.A. (“CPFL Centrais Elétricas”) and SEMESA S.A. (“SEMESA”) (see “2007’s Restructuring transactions and acquisitions”), in addition to participating in the capital of other companies, the subsidiary CPFL Geração started operating as a public electric energy generation concessionaire. It owns 19 small hydropower plants and 1 thermal power plant, with total installed capacity of 120 MW and 36 MW, respectively, all located in the State of São Paulo. Its concession term ends in 2027 and may be extended for an additional 30 years period. It also has an interest in Aproveitamento Hidrelétrico da Serra da Mesa, located on the Tocantins river in the State of Goiás. The concession and operation of the Hydropower plant belong to Furnas Centrais Elétricas S.A. (“FURNAS”). These assets were leased to FURNAS under an agreement with a term of 30 years, starting in 1998, which assured SEMESA of a share of 51.54% of the installed capacity of 1,275 MW (657 MW) and average assured energy of 671 MW (average of 345.8 MW). CPFL Geração, also holds the concession and the related assets of the Ponte do Silva small hydropower plant (PCH), with total power of 125 kW, located on the São Luiz River, in the State of Minas Gerais, granted in October 1989 for a 30 year term.

CPFL Sul Centrais Elétricas Ltda (“CPFL Sul Centrais Elétricas”)

CPFL Sul Centrais Elétricas is a Brazilian limited liability company that owns 4 small hydroelectric power plants, all located in the state of Rio Grande do Sul, with total installed generation capacity of 2.65 MW and assured energy of 2.45 MW average.

BAESA — Energética Barra Grande S.A. (“BAESA”) (jointly-controlled)

BAESA is a Brazilian public company, engaged in the construction and operation of hydroelectric resources of the Barra Grande power plant (located on the Pelotas River, on the borders of the States of Santa Catarina and Rio Grande do Sul). The total installed generation capacity is 690 MW, according to the concession agreement, equally divided in three power plants that have started commercial operations in November 2005, February 2006 and May 2006. Its concession term ends in 2036, and may be extended in accordance with the conditions established by the Granting Authority.

Campos Novos Energia S.A. (“ENERCAN”) (jointly-controlled)

ENERCAN is a Brazilian private corporation engaged in the construction and operation of hydroelectric resources of the Campos Novos power plant (located on the Canoas River, in the State of Santa Catarina). The installed capacity is 880 MW. Commercial operations started in 2007 (2 turbines started operating in February and the last turbine in May). Its concession term ends in 2035, and may be extended in accordance with the conditions established by the Granting Authority.

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Paulista Lajeado Energia S.A. (“Paulista Lajeado”)

Paulista Lajeado, a Brazilian private corporation, holds 6.93% of the shared concession relating to the Luis Eduardo Magalhães Hydropower Plant – Lajeado, which has an installed capacity of 902.5 MW. Paulista Lajeado also has a 5.84% share in the total capital of Investco S.A. (“Investco”), which holds the assets of the Hydropower Plant. These assets were leased to the controlling shareholders under a lease agreement and the portion relating to Paulista Lajeado's share of the plant's assured energy (6.93%) is negotiated with the subsidiaries CPFL Leste Paulista, CPFL Sul Paulista, CPFL Jaguari and CPFL Mococa. Its concession term ends in 2032, and may be extended in accordance with the conditions established by the Granting Authority.

Development Stage Companies

CPFL Geração holds interests in new generating ventures, which are expected to be completed by 2010, increasing its installed capacity, proportionately to its equity interest, to 2,087 MW. This capacity, together with the installed capacity of the subsidiaries of CPFL Jaguariúna will provide a total consolidated installed capacity of 2,174 MW. These projects are:

CERAN — Companhia Energética Rio das Antas (“CERAN”) (jointly-controlled)

CERAN, a Brazilian private corporation, is engaged in the implementation and operation of hydroelectric resources of the Monte Claro, Castro Alves and 14 de Julho power plants (located in the State of Rio Grande do Sul). Total installed generation capacity of these power plants will be 360 MW. The Monte Claro and Castro Alves power plants (each with 130 MW) began operating in December 2004 and March 2008, respectively. The 14 de Julho power plant will begin in 2008. Its concession term ends in 2036, and may be extended by an additional period of 35 years.

Foz do Chapecó Energia S.A. (“Foz do Chapecó”) (jointly-controlled)

Foz do Chapecó, a Brazilan private corporation, is engaged in the construction, operation and exploitment of the Foz do Chapecó Hydropower Plant (located on the Uruguai River on the border of the States of Santa Catarina and Rio Grande do Sul), with planned installed capacity, established in the concession contract, of 855 MW. Construction work started in 2006 and commercial operations are scheduled to start in 2010. Its concession term ends in 2036, and may be extended in accordance with the conditions established by the Granting Authority.

Commercialization activities

CPFL Comercialização Brasil S.A. (“CPFL Brasil”)

CPFL Brasil, is a Brazilian private corporation, whose business purpose is to sell energy, provide associated services, linked with the sale of energy, strategic, institutional and financial advisory services for purchasers and sellers of electric energy and for other organizations operating in the national and international energy sector. CPFL Brasil is authorized to act as an electric power retail agent in the Electric Energy Trading Chamber (“CCEE”).

Clion Assessoria e Comercialização de Energia Elétrica Ltda. (“CPFL Meridional”)

CPFL Meridional is a Brazilian limited liability company, whose business purpose is to sell energy and provide services in the energy field. It is authorized to act as a retail agent for electric power in the CCEE.

Sul Geradora Participações S.A. (“Sul Geradora”)

Sul Geradora, is a Brazilian private corporation, with the main purpose of participating in the capital of other companies.

CPFL Comercialização Cone Sul S.A. (“CPFL Cone Sul”)

CPFL Cone Sul is a Brazilian private corporation, whose business purpose is to sell energy. CPFL Cone Sul is authorized to act as an electric power retail agent in the CCEE.

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CPFL Planalto Ltda (“CPFL Planalto”)

CPFL Planato is a Brazilian limited liability company, whose business purpose is to sell energy. It is authorized to act as an electric energy retail agent in the ambit of the CCEE.

CPFL Serviços, Equipamentos, Indústria e Comércio S.A. (“CPFL Serviços”)

CPFL Serviços is a Brazilian private corporation, whose business purpose is to service provision in two business sectors: generation, transmission and distribution of electric energy and the transmission, distribution and storage of natural gas.

Other Holding Companys

Perácio Participações S.A. (“Perácio”)

Perácio is a Brazilian private corporation, whose business purpose is to hold interest in the capital of other companies.

CPFL Jaguariúna S.A. (“CPFL Jaguariúna”)

CPFL Jaguariúna, a Brazilian private corporation, was set up with the main objective of acting as a holding company, and holds direct and indirect shares in public utilities companies that provide generation, distribution and sale of electric energy services.

Makelele Participações S.A. (“Makelele”)

Makelele is a Brazilian private corporation, whose business purpose is to hold interest in other companies, either exercising control or permanently holding interest with significant investments in their capital. However, it currently holds no such participations.

Companhia Jaguari de Geração de Energia (“Jaguari Geração”)

Jaguari Geração is a Brazilian private corporation and was set up to operate in the generation, distribution and sale of electric energy.

Chumpitaz Participações S.A. (“Chumpitaz”)

Chumpitaz is a Brazilian private corporation, whose business purpose is to hold interest in the capital of other companies. However, it currently holds no such participations.

2007’s Restructuring transactions and acquisitions

• RGE restructuring transactions

In 2007, several restructuring transactions were made in order to allow RGE to become a wholly-owned subsidiary of CPFL Energia. Those transactions are described below:

- Transfer of share control from CPFL Paulista to CPFL Serra:

In the Extraordinary General Meeting held on March 14, 2007, the shareholders approved the transfer of the share control of RGE, in the form of a reduction in the capital of the subsidiary CPFL Paulista, through the return to the Company of 67.0686% of RGE's capital amounting to total assets of R$ 1,050,411. The Company transferred these assets to the subsidiary CPFL Serra on the same date. The transfer was in compliance with ANEEL Authorization Resolution n° 305, of September 5, 2005 and ANEEL Order n° 669 of March 14, 2007, in relation to the need for corporate segregation laid down in Law 10.848, of March 15, 2004. These assets were appraised at book values, in accordance with an appraisal report, as of December 31, 2006. All RGE's balances and transactions, from January 1, 2007 to June 30, 2007, were consolidated through CPFL Serra. This restructuring had no effect on the Company’s shareholders equity or results of operation on the date of the restructuring.

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- Merger of the indirect subsidiary CPFL Serra by RGE:

As authorized by ANEEL, the Extraordinary General Meeting held on September 18, 2007 approved the merger of CPFL Serra by the subsidiary RGE. The merged company was therefore terminated, and the subsidiary RGE succeeded to its assets, rights and obligations. The main objective of the merger was to simplify the group's corporate and administrative structures. As the appraisal at book value for the merger was prepared as of June 30, 2007, as from July 1, 2007, all RGE's balances and transactions are directly reflected in the financial statements of the Company. This restructuring had no effect on the Company’s shareholders equity or results of operation on the date of the restructuring.

- RGE’s minority shareholders acquisition (merger of shares)

In an Extraordinary General Meeting held on December 18, 2007, the Company approved the merger of RGE shares held by the minority shareholders, converting it into a wholly-owned subsidiary. The exchange ratio, based on the evaluation reports, was 1 (one) common share in the Company to every 15.5126288900 common or preferred shares in RGE. This merger resulted in a capital increase of R$ 6,385 in the Company, through the issuing of 154,208 common shares. The goodwill recorded in this transaction was R$ 3,150.

• Nova 4 and CPFL Santa Cruz merger

The merger of the subsidiary Nova 4 by the subsidary CPFL Santa Cruz was authorized by ANEEL and approved in an Extraordinay General Meeting held on November 14, 2007. The merged company was therefore terminated, and the subsidiary CPFL Santa Cruz succeeded to its assets, rights and obligations. As the appraisal at book value for the merger was prepared as of October 31, 2007, as from November 1, 2007, all CPFL Santa Cruz's balances and transactions are directly reflected in the financial statements of the Company. This restructuring had no effect on the Company’s shareholders equity or results of operation on the date of the restructuring.

• Merger of CPFL Centrais Elétricas and SEMESA by CPFL Geração

The merger of the indirect subsidiaries CPFL Centrais Elétricas and SEMESA (“Merged Companies”) by the parent company CPFL Geração was authorized by ANEEL and Banco Nacional de Desenvolvimento Econômico Social – BNDES, and approved in an Extraordinay General Meeting held on March 30, 2007. The merged companies were therefore terminated, and the subsidiary CPFL Geração succeeded to their assets, rights and obligations. As the shareholders’ equity of the merged companies was appraised at the book values as of December 31, 2006, analysis of the financial statements as of December 31, 2007 should take into account the effects of the merger of these investments as from January 1, 2007. This restructuring had no effect on the Company’s shareholders equity or results of operation on the date of the restructuring.

• Foz do Chapecó – Corporate Reorganization

The corporate reorganization of Foz do Chapecó, as authorized by ANEEL, was approved in the Extraordinay General Meeting held on July 16, 2007, and resulted in termination of the Foz do Chapecó Consortium (“CEFC”) and in Chapecoense Geração S.A. (“Chapecoense”) becoming a Foz do Chapecó shareholder. However, the restructuring maintained the partners’ participation in the project (51% of the subsidiary CPFL Geração) now directly in Foz do Chapecó. This restructuring had no effect on the Company’s shareholders equity or results of operation on the date of the restructuring.

• CPFL Jaguariúna acquisition

In June 2007, the Company signed the final purchase agreement with CMS Electric & Gas, LLC to acquire the equity interest of CPFL Jaguariúna (former CMS Brasil). The acquisition was made through the subsidiary Peracio that acquired 100% of CPFL Jaguariúna’s total capital comprising of 94,810,080 common shares and 94,810,080 preferred shares. This transaction was approved by ANEEL in June 2007. The total cost of this acquisition was USD 211 million which amounted to R$ 411,943 after currency translation and other direct costs. The goodwill recorded in this acquisition amounted to R$ 142,793.

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In the acquisition date, CPFL Jaguariúna held interest in (i) 4 distribution concessionaires such as CPFL Leste Paulista, CPFL Jaguari, CPFL Sul Paulista, and CPFL Mococa; (ii) a generation asset through Jaguari Geração and Palista Lajeado, increasing our installed generation capacity by 86.8 MW; and (iii) CPFL Planalto and CPFL Serviços, which are engaged in the commercialization and the services support for custumers related to the energy sector.

2. SIGNIFICANT ACCOUNTING POLICIES

The accompanying consolidated financial statements are presented in thousands of Brazilian reais (R$) and were prepared in accordance with accounting practices adopted in Brazil, which include accounting practices established by Brazilian corporate law and regulations issued by ANEEL and the Brazilian Securities Commission (“CVM”) (herein after referred to as “Brazilian Accounting Principles”).

In order to provide a basis for comparison with the financial statements for the period ended December 31, 2007, some subsidiaries made certain reclassifications, basically as a result of the new classifications and rules required by ANEEL, in accordance with Order No. 3,073, which made changes to the Public Electric Energy Service Accounting Manual:

Item		From		To
Fuel Consumption Account - CCC		Operating Expenses		Deductions from Operating Revenue
Energy Development Account - CDE		Operating Expenses		Deductions from Operating Revenue
Research and Development and Energy Efficiency Programs		Operating Expenses		Deductions from Operating Revenue

The accompanying financial statements are a translation and adaptation from those originally issued in Brazil, prepared in accordance with Brazilian Accounting Principles. In addition to the adjustments described above, the Company made certain reclassifications, modifications and changes in terminology in order to conform more closely to reporting practices prevailing in the United States of America.

Use of Estimates

The preparation of financial statements in accordance with Brazilian Accounting Principles requires the Company’s management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses in the financial statements. Although these estimates are based on the Company’s knowledge of current events and actions the Company may undertake in the future, actual results may ultimately differ from those estimates.

Consolidation Principles

The Company accounts for investments in jointly-controlled subsidiaries using proportionate consolidation. All notes to the consolidated financial statements have also been prepared on a proportionate-consolidation basis. The Company calculates the proportionate-consolidation method by applying its percentage ownership interest to the financial statements of its jointly-controlled subsidiaries. The use of the proportionate-consolidation method has been approved by the CVM. Although the use of the proportionate-consolidation method as compared to the equity method of accounting from a financial presentation perspective impacts almost all areas of the Company’s consolidated balance sheets and consolidated statements of income, it does not impact the Company’s consolidated shareholders’ equity or net income (loss).

All significant intercompany balances and transactions have been eliminated in these financial statements. Additionally, the accounting policies of CPFL Energia’s subsidiaries have been conformed to those of CPFL Energia. The principal difference in accounting policies relates to the revaluation of property, plant and equipment recorded by RGE, which is reversed in consolidation.

The consolidated financial statements cover the balances and transactions of the Company and its subsidiaries CPFL Paulista, CPFL Piratininga, CPFL Serra (up to June 30, 2007), RGE (as from July 1, 2007), Nova 4 (up to October 30, 2007), CPFL Santa Cruz (as from November 1, 2007), CPFL Geração, CPFL Brasil, Chumpitaz and Perácio (see corporate restructuring in Note 1). The asset, liability, income and expense balances were fully consolidated. Prior to consolidation into the Company's financial statements, the financial statements of CPFL Geração, CPFL Brasil and Perácio are consolidated with those of their subsidiaries, fully (majority) controlled subsidiaries or proportionally (jointly) controlled subsidiaries, according to the rules defined in CVM Instruction No. 247/96.

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In compliance with the conditions described above, the portion relating to the non-controlling shareholders is stated separately in liabilities and income statements for the fiscal year.

All significant intercompany balances and transactions have been eliminated.

The Company’s subsidiaries, by segment, are as follows:

				2007				2006
		Consolidation		Equity Interest - %				Equity Interest - %
Subsidiary		Method		Direct		Indirect		Direct		Indirect
Energy Distribution
Companhia Paulista de Força e Luz		Full		100.00		-		100.00		-
Companhia Piratininga de Força e Luz		Full		100.00		-		100.00		-
Companhia Luz e Força Santa Cruz		Full		99.99		-		-		99.99
Rio Grande Energia S.A.		Full		100.00		-		-		99.76
Companhia Paulista de Energia Elétrica		Full		-		96.56		-		-
Companhia Jaguari de Energia		Full		-		90.15		-		-
Companhia Sul Paulista de Energia		Full		-		87.80		-		-
Companhia Luz e Força Mococa		Full		-		89.75		-		-
Energy Generation
CPFL Geração de Energia S.A		Full		100.00		-		100.00		-
CPFL Centrais Elétricas S.A		Full		-		-		-		100.00
SEMESA S.A.		Full		-		-		-		100.00
CPFL Sul Centrais Elétricas Ltda		Full		-		100.00		-		100.00
Paulista Lajeado Energia S.A.		Full		-		54.03		-		-
CERAN - Companhia Energética Rio das Antas		Proportionate		-		65.00		-		65.00
BAESA - Energética Barra Grande S.A		Proportionate		-		25.01		-		25.01
Foz do Chapecó Energia S.A		Proportionate		-		51.00		-		51.00
Campos Novos Energia S.A		Proportionate		-		48.72		-		48.72
Energy Commercialization
CPFL Comercialização Brasil S.A		Full		100.00		-		100.00		-
CPFL Comercialização Cone Sul S.A		Full		-		100.00		100.00		-
Clion Assessoria e Comercialização de Energia Elétrica Ltda.		Full		-		100.00		-		100.00
Sul Geradora Participações S.A		Full		-		99.95		-		99.95
CPFL Planalto Ltda. (former CMS Comercializadora de Energia Elétrica)		Full		-		100.00		-		-
Services
CPFL Serviços, Equipamentos, Indústria e
Comércio S.A. (former CMS Energy,
Equipamentos, Serviços, Indústria e Comércio S.A.)		Full		-		89.81		-		-
Holding Company
Nova 4 Participações Ltda		Full		-		-		100.00		-
CPFL Serra Ltda		Full		-		-		100.00		-
Perácio Participações S.A.		Full		100.00		-		-		-
Chumpitaz Participações S.A.		Full		100.00		-		-		-
Makelelê Participações S.A.		Full		-		100.00		-		100.00
CPFL Jaguariúna (former CMS Energy Brasil S.A.)		Full		-		100.00		-		-
Companhia Jaguari de Geração de Energia		Full		-		90.15		-		-

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Revenue recognition

Electricity distribution revenue are recognized based on tariffs that are regulated by ANEEL, when the electricity is provided (see Note 3 for additional information on the regulatory environment in Brazil). Unbilled revenue from the billing cycle through the end of each month is accrued based on the actual amount of energy provided during the month and the annualized energy loss rate. Differences between estimated and actual unbilled revenues, which historically have not been significant, are recognized in the following month. Revenue from the sale of electricity generation is recorded based on assured energy provided at rates specified under contract terms or prevailing market rates. All revenues are presented in a gross basis and the taxes on revenues are presented as a “Deduction from Operating Revenues”.

No single customer accounted for 10% or more of the Company’s revenues for any of the three years ended December 31, 2007.

Cash and cash equivalents

The Company considers unrestricted cash on hand, deposits in banks, certificates of deposit and liquid investments with original maturities of three months or less to be cash and cash equivalents. Interest earned is accrued to the balance sheet date.

Financial investments

Financial Investments are stated at the lower of cost plus accrued income earned (on a “pro rata temporis” basis), or fair value. Short-term financial investments represent debt security trading investments with maturities of over three months stated at fair value.

Accounts receivable

Accounts receivable includes both billed and unbilled supply of electricity to final consumers and to other concessionaires. It also includes amounts related to the regulatory assets of different kinds, recorded on the accrual basis.

Allowance for doubtful accounts

An allowance for doubtful accounts is calculated based on an analysis of the Company’s receivables from residential consumers that are over 90 days past due, from commercial consumers that are over 180 days past due, and from other consumers (such as public sector entities) that are over 360 days past due. An allowance is also recorded based on an analysis of the balances of the larger customers for which collection is considered doubtful and the Company’s collection experience, including amounts due from public sector entities and those with installment terms.

Property, plant and equipment

Property, plant and equipment are stated at acquisition or construction cost, as applicable, updated to reflect price-level changes related to inflation through December 31, 1995, and are depreciated at annual rates that range from 2% to 20%, in accordance with the nature of the asset.

Interest, other financial charges and inflationary effects related to financing obtained from third parties, invested in fixed assets in progress, are capitalized. As established by specific legislation for Electric Energy Public Service, the interest on capital that financed the fixed assets was capitalized through March 2000. Additionally, through March 2002, the Company capitalized administrative expenses under fixed assets in progress by apportioning 10% of the expenses on personnel and outsourced services involved in the fixed assets, and beginning 2005, administrative expenses are being capitalized by apportioning personnel expenses based on the time spent on the activities linked to the investments. The Company decided to recommence capitalization of administrative expenses after technical studies to apportion these expenses.

Significant improvements to property, plant and equipment are capitalized if they extend the useful life of the asset. Routine repairs and maintenance are expensed when incurred. The net results of disposals of fixed assets are recorded as part of nonoperating income.

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The Company reviews long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by comparing the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment recognized is measured by comparing the carrying amount of the assets to the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs related to the sale. No impairment of long-lived assets has been recorded in the accompanying financial statements.

Goodwill

Goodwill recorded on the acquisition of subsidiaries represents the difference between the purchase price paid and the book value of the Company acquired. The goodwill is amortized proportionately to the future projected net income for the remaining term of the concession contract of each investee, as required by ANEEL.

Monetary Restatement of Assets and Liabilities

Assets and liabilities that are indexed to inflation or exchange rate variations by contract or due to legal provisions are updated to the balance sheet date.

Income and Social Contribution Taxes

Income and social contribution taxes are calculated based on the legislation in effect at the balance sheet date. The Company recognized the effects of income and social contribution tax credits on tax loss carryforwards and temporary differences, supported by projections of future generation of taxable income, in a period not to exceed 10 years. Some subsidiaries also recorded tax credits referring to the benefit of the goodwill merged, which are being amortized proportionally to the projected net income for the remaining period of the concession contract of each investee. The amortization rates were determined in a projection approved by ANEEL in 2004 and are subject to periodic review.

Post-retirement benefit obligation

The Company’s subsidiaries, together with other energy companies in Brazil, sponsor certain private pension plan foundations to manage its pension funds (defined benefit and defined contribution) and other pension benefits of the Company’s employees.

On December 13, 2000, the CVM enacted Resolution No. 371 (“CVM 371/2000”), approving the Brazilian Institute of Independent Auditors (IBRACON) Pronouncement on Accounting for Employees’ Benefit Plans and establishing new accounting practices for computing, recording and disclosing the effects of employee benefit plans in Brazil. CVM Resolution No.371/2000 requires that companies record pension and post-retirement benefits on an accrual basis. In accordance with CVM Resolution No.371/2000, the Company elected to record the actuarial liabilities in excess of plan assets as of December 31, 2001 based on the projected unit credit method and amortized the effect over five years, beginning January 2002.

Reserve for Contingencies

A reserve for contingencies is recognized by the Company’s management based on their assessment evaluating the risks involved in lawsuits in which loss is considered probable and quantified based on economic grounds, as assessed by management and the legal counsel in legal opinions on the existing cases and other contingency-related facts known at the balance sheet dates. The reserve for contingencies is presented, net of its related escrow deposit pursuant to CVM Resolution No. 489.

Loans and Financing

Restated in accordance with the monetary and exchange variations, including charges,

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Derivatives

The Company enters into swap derivative contracts to manage its exposure to market risk associated with changes in interest and foreign exchange rates. The Company accounts for derivative on an accrual basis. For all periods presented, the Company did not enter into derivative contracts that qualify for hedge accounting.

The Company’s derivative are with counterparties that are high-quality commercial banks with significant experience with such instruments. The Company does not enter into derivative for speculative purposes.

Share and per share information

As required by Brazilian accounting principles, share and per share information refers to the historical number of shares effectively outstanding at the balance sheet date. Earnings per share is determined by dividing the Company’s net income for the year by the number of shares outstanding at year-end.

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3. REGULATORY ASSETS AND LIABILITIES

A summary of the regulatory assets and liabilities recorded is as follows:

		Current				Noncurrent
		2007		2006		2007		2006
Assets
Accounts receivable (note 6)
RTE — Extraordinary tariff adjustment (a)		3,448		210,517		456		-
Free energy (a)		1,924		74,500		480		790
Tariff review - Remuneration basis (b.1)		1,443		28,484		-		-
Tariff review - Depreciation (b.1)		13,147		34,341		-		12,604
Tariff adjustment - Others (b.3)		1,769		-		95		-
Discounts on TUSD and irrigation (b.3)		64,235		31,078		19,637		7,970
		85,966		378,920		20,668		21,364
Deferred cost variations
Parcel "A" (a)		343,233		102,460		167,716		460,721
CVA (c)		189,216		231,893		38,178		51,957
		532,449		334,353		205,894		512,678
Prepaid expenses (note 9)
Tariff adjusment – Itaipu purchase		-		13,052		-		-
Tariff adjustment – Others (b.3)		20,001		17,982		42		6,904
PIS and COFINS - Generators pass-through (b.3)		1,210		22,447		-		3,473
Increase in PIS and COFINS (b.3)		25,097		47,106		-		3,554
Energy surpluses and shortfalls (b.3)		81,704		30,102		28,605		5,467
Low income consumers' subsidy - Losses (d)		55,967		47,393		-		-
		183,979		178,082		28,647		19,398
Liabilities
Suppliers (note 14)
Free energy (a)		(35,609)		(103,581)		(223)		-
Deferred gains variations
Parcel "A" (a)		(9,668)		-		(4,890)		(12,335)
CVA (c)		(220,370)		(162,350)		(63,499)		(58,734)
		(230,038)		(162,350)		(68,389)		(71,069)
Other liabilities (note 21)
PIS and COFINS - Generators pass-through (b.3)		(8)		(15,010)		-		-
Reimbursement to the consumer – IRT recalculation
(b.3)		(26,213)		-		-		-
Tariff Adjustment – Others (b.3)		(1,492)		-		(54)		-
Increase in PIS and COFINS (b.3)		(113,964)		(30,842)		-		-
Energy surpluses and shortfalls (b.3)		(130)		-		(12)		-
Low income consumers' subsidy - Gains (d)		(8,553)		(3,964)		(71)		(732)
		(150,360)		(49,816)		(137)		(732)
Total		386,387		575,608		186,460		481,639

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a) Rationing

At the end of 2001, as a result of the Emergency Program for Reduction of Electric Energy Consumption (“Energy Rationing Program”), which remained in effect between June 2001 and February 2002, an agreement was signed between the generators, power distributors and the Federal Government, called the “Overall Agreement for the Electric Energy Sector”, which introduced an Extraordinary Tariff Adjustment of 2.9% on electric power supply tariffs to rural, public lighting and residential consumers (except those considered to be “low income consumers”) and 7.9% for all other consumers, as a mechanism to reimburse the losses incurred by the electricity sector with the rationing program.

This adjustment is being used to offset the following regulatory assets recorded by the subsidiaries:

				Free Energy (2)				Parcel "A"
Description		RTE (1)		Asset		Liability		Net (3)
Ratified Amount		925,347		374,639		(355,579)		231,029
Monetary restatement		727,904		290,784		(289,283)		386,344
Provision for losses		(154,111)		(203,682)		190,493		-
Amount amortized		(1,495,236)		(459,337)		418,537		(120,982)
Balances to be Amortized as of December 31, 2007		3,904		2,404		(35,832)		496,391

(1) ANEEL resolutions n° 480/02, 481/02 and 01/04.
(2) ANEEL resolutions n° 483/02 and 01/04.
(3) ANEEL resolutions n° 482/02 and 01/04.

The changes in balances related to RTE, Free Energy and Parcel “A” are as follows:

				Free Energy				Parcel "A"
Description		RTE (1)		Asset (2)		Liability		Net
Balances as of December 31, 2004		599,711		291,128		321,712		399,753
Monetary restatement		160,346		101,387		94,085		76,153
Provision for losses		(84,902)		(6,904)		-		-
Realization/Payment		(258,143)		(100,810)		(123,597)		-
Balances as of December 31, 2005		417,012		284,801		(292,200)		475,906
Assets added to the consolidated due to acquisition of
equity interests		-		1,395		(1,503)		3,187
Monetary restatement		51,488		43,669		(58,519)		71,753
Provision for losses		-		(146,606)		145,568		-
Realization/Payment		(257,983)		(107,969)		103,073		-
Balances as of December 31, 2006		210,517		75,290		(103,581)		550,846
Assets added to the consolidated due to acquisition of
equity interests		5,249		2,977		(3,814)		1,723
Monetary restatement		20,542		27,654		(24,344)		61,480
Provision for losses		(8,744)		(45,916)		44,925		-
Realization/Payment		(223,660)		(79,964)		71,115		(117,658)
Tax adjustments – Technical note 392/2007 –
SFF/ANEEL		-		22,363		(20,133)		-
Balances as of December 31, 2007		3,904		2,404		(35,832)		496,391

(1) R$ 150 was recorded in Operating Revenue, line "Realization of Extraordinary Tariff Adjustment ", in relation to amortization of the Parcel "A" liability.
(2) The effects of amortization in 2007 were recorded in Operating Revenue R$ 76,487 (R$ 103,406 in 2006) and Accounts Receivable R$ 3,477 (R$ 4,563 in 2006).

F - 19

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• Extraordinary Tariff Adjustment (“RTE”) – Corresponds to the loss of revenue incurred during the rationing period. This asset was determined from a comparison between the sales revenues from energy effectively recorded in the period between June 1, 2001 and February 28, 2002, and projected revenue for this period not considering the occurrence of the Energy Rationing Program.

The RTE balance refers to the indirect subsidiary CPFL Sul Paulista, which established a provision for losses of R$ 2,021, based on estimated projections of revenue, taking into consideration the market growth and expectations of inflation, interest and regulatory aspects. The deadline established by ANEEL for recovery of the RTE by CPFL Sul Paulista is January 2009.

Considering that there is a period to recover the RTE established by ANEEL, as of December 31, 2007, the Company recorded loss of R$ 152,090 for CPFL Paulista and CPFL Piratininga, due to failure to realize this asset The subsidiaries CPFL Leste Paulista, CPFL Jaguari and CPFL Mococa realized the full amount of the RTE in June 2005, December 2004 and December 2006, respectively.

• Electricity from Independent Suppliers (“Free Energy”) – Corresponds to the energy produced and made available to the consumer market during the rationing period by independent producers and self-producers of energy.

The distribution utilities collected the funds from the consumer through the extraordinary tariff adjustment and passed them on to the generators, using parameters determined by ANEEL. Accordingly, an asset and a liability were recorded. These amounts are monetarily restated in accordance with the ANEEL instructions.

As a result of the end of the term for collection of RTE in 2007, the subsidiaries CPFL Paulista and CPFL Piratininga recorded Free Energy losses in the total amount of R$ 188,755. The asset was written off against the Other Operating Expenses - Sales and the liability was written off in Other Operating Income, having no impact on the income of the subsidiaries. The subsidiary CPFL Jaguari also recorded Free Energy losses of R$ 365 in 2007. The subsidiary CPFL Sul Paulista established a provision for losses on free energy in the amount of R$ 1,738.

The Free Energy regulatory asset recorded by RGE originates from spot market sales made during the energy rationing program, relating to its share of the Itaipu energy. Accordingly, as of December 31, 2007, the subsidiaries RGE and CPFL Geração have recognized a provision of R$ 12,824 for losses on the realization of Free Energy.

• Parcel “A” – Corresponds to the variation in unmanageable costs, defined as Parcel “A” in the concession contracts, between January 1 and October 25, 2001. These amounts are monetarily restated based on the variation in the SELIC rate.

In the case of the subsidiary CPFL Piratininga, offsetting of Parcel “A” started as from February 2007, using a mechanism similar to that used for the RTE. For the subsidiaries CPFL Paulista and CPFL Sul Paulista, respectively, amortization of parcel “A” will start from January 2008 and February 2009, over the period required to reach the amount recorded. In the case of the subsidiaries CPFL Santa Cruz, CPFL Leste Paulista, CPFL Mococa and CPFL Jaguari, Parcel “A” was fully amortized in November 2007, September 2005, March 2007 and August 2005, respectively.

The amortization of Parcel “A” in 2007 referring to CPFL Piratininga and CPFL Santa Cruz is as follows:

		2007
Energy purchased		84,838
System service charge		5,477
Fuel consumption account - CCC		24,742
RGR		1,881
Inspection fee		720
Total		117,658

F - 20

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b) Tariff Review and Tariff Adjustment

b.1) First cycle of periodic tariff review (2003/2004)

i) CPFL Paulista – Depreciation

In 2007, by Ratification Resolution n° 443, ANEEL amended the final result of the first periodic Tariff Review of the subsidiary CPFL Paulista, approved in April 2005, adjusting the energy supply tariffs by 20.66%, due to a review of the calculation of the average depreciation percentage used in the 2003 tariff review. The difference in income resulting from the change in the tariff adjustment from 20.29% to 20.66%, and of the Xe component of the X Factor from 1.1352% to 1.2530%, corresponds to a financial adjustment of R$ 44,868, which is being offset in the 2007 tariff adjustment. This regulatory asset was recorded in the “Consumers, Concessionaires and Licensees – Tariff Review - Depreciation” account, including the effects of PIS and COFINS, and since the annual adjustment, it has been amortized.

ii) CPFL Piratininga – Remuneration Base

In 2006, by Ratification Resolution n° 385, and in response to the application filed by Bandeirante Energia S.A. (“Bandeirante”) for reconsideration of the tariff review, ANEEL amended the amounts of the CPFL Piratininga remuneration base.

In accordance with this amendment, ANEEL established that the electric energy supply tariffs should be reset at 10.14% . Accordingly, in accordance with the new provisional percentage established by ANEEL, the subsidiary CPFL Piratininga recorded a regulatory asset of R$ 26,970 in 2006, including PIS and COFINS, set against Revenue from Electric Energy Operations.

ANEEL Resolution n° 336, of 2001, concerning approval of the request for spin-off of Bandeirante and the partial transfer of its concession area to the subsidiary CPFL Piratininga, established that, in the first periodic Tariff Review, the lower of the rates of the two concessionaires would apply. As the rate for Bandeirante was 10.14%, against 11.52% for the subsidiary CPFL Piratininga, the rate of 10.14% applies.

ANEEL Order n° 3209, of October 22, 2007, ratified the result of the Company’s first tariff Review, making it final.

iii) CPFL Santa Cruz, CPFL Mococa and CPFL Leste Paulista – Remuneration Base

In 2005, ANEEL finally approved the results of the first periodic Tariff Review of February 2004 for the subsidiaries CPFL Santa Cruz, CPFL Leste Paulista, CPFL Sul Paulista, CPFL Jaguari and CPFL Mococa. The differences between the provisional and the final percentages for the subsidiaries CPFL Santa Cruz, CPFL Leste Paulista and CPFL Mococa were deferred to the next tariff adjustments and recovery is expected to continue until January 2008.

b.2) Second cycle of periodic tariff review (2007/2008)

By Ratification Resolution n° 553, ANEEL provisionally readjusted the tariffs of the subsidiary CPFL Piratininga by -10.11%, of which -10.94% refers to the tariff adjustment and 0.83% to the financial components not included in the periodic tariff review.

As a result of the elimination from the tariff base of financial components added in the 2006 annual adjustment, the average effect for consumers will be -15.29% .

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The adjustment authorized by ANEEL comprises the following items:

Verified Revenue		2,136,914
Parcel A		1,423,875
Gross remuneration base		154,530
Depreciation		81,098
Reference company		244,232
Delinquency		12,619
Parcel B		492,479
Required revenue (Parc. A + B)		1,916,354
(-) Other revenues		(13,152)
Net required revenue		1,903,202
Financial components		15,767
Financial repositioning		-10.94%
Financial components		0.83%
Total repositioning		-10.11%

Calculation of Parcel A comprises:

• Sector charges of R$ 257,170 (of which CCC and CDE account for 78%);
• Energy Purchased amounting to R$ 954,779;
• Energy Transmission, amounting to R$ 211,926.

The financial components external to the tariff review comprise:

• Deferred Tariff Costs and Gains Variations (“CVA”) amounting to R$ 3,918;
• Overcontracting of Electric Energy amounting to (R$ 3,304) (negative effect);
• Discounts on collection of the Tariff for Use of the Distribution System (“TUSD”) amounting to R$ 8,342;
• Adjustments of Connection Charges, Basic Network and CUSD amounting to R$ 5,744;
• Other components totaling R$ 1,067.

Additionally, a provisional Xe Factor of 0.73% was established, to be applied as a reduction factor for “Parcel B” in the subsequent 2008, 2009 and 2010 tariff adjustments.

b.3) 2007 Tariff Adjustments

The Annual Tariff Review - IRT of the electric energy distributors is the sum of the economic tariff review and the additional financial components. The Ratification Resolutions and the breakdown of the annual tariff review for the Company’s directly and indirectly controlled electric energy distributors are shown in the following table:

				% Annual		%		% Total
				Adjust-		Financial		Adjust-
Distributor		Ratification Resolution		ment		Components		ment
CPFL Santa Cruz		Resolution 424, of January 30, 2007		4.56%		1.15%		5.71%
CPFL Leste Paulista		Resolution 419, of January 30, 2007		3.52%		-0.21%		3.31%
CPFL Sul Paulista		Resolution 423, of January 30, 2007		1.64%		3.88%		5.52%
CPFL Jaguari		Resolution 421, of January 30, 2007		-0.38%		2.04%		1.66%
CPFL Mococa		Resolution 420, of January 30, 2007		6.70%		2.91%		9.61%
CPFL Paulista		Resolution 445, of April 3, 2007		2.60%		4.46%		7.06%
RGE		Resolution 452, of April 18, 2007		3.77%		2.28%		6.05%
CPFL Piratininga		See 2nd Tarif Review Cycle

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Besides CVA (see item “c”), the main additional financial components are as follows:

• Increase in PIS and COFINS

Refers to the difference between the costs relating to PIS and COFINS calculated in accordance with the current legislation, and those incorporated in the tariff until April 2005.

The amounts approved by ANEEL and the respective amounts recorded in the statements of income for 2007, 2006 and 2005 are shown in the following table:

		Total		Recording of PIS and Cofins
		Amount		increase - Asset
Distributor		Approved		2007		2006		2005
CPFL Paulista		112,728		72,983		-		4,221
CPFL Piratininga		41,870		-		30,842		11,099
RGE		23,412		569		-		5,488
		178,010		73,552		30,842		20,808

These amounts were recorded in the “Prepaid Expenses” account (note 9).

In view of the discussions in respect of the nature of this credit, the Company opted to record a liability of the same amount, recorded in the account “Other Accounts Payable” (note 21), which is monetarily restated based on the variation of the IGP-M.

• Energy Surpluses and Shortages:

The distribution concessionaires are required to guarantee 100% of their energy and electricity market through contracts approved, registered and ratified by ANEEL. They also guarantee to pass through to tariffs the cost or income from excess or shortage of electricity of the distribution concessionaires, limited to 3% of the energy load requirement.

The net energy surpluses, for 2007 and 2006, were made available to the CCEE for spot market sale, and were consequently settled at the spot market price, which is lower than the average price defined in the Tariff Adjustment Index.

The price difference between the cost of the surplus energy and the actual sale value on the spot market is being recorded as Prepaid Expenses (note 9) against Cost of Electric Energy (note 24).

• Discounts on the TUSD and Irrigation

The subsidiaries record regulatory assets for (i) the special discounts applied on TUSD regarding of supplying electricity from alternative sources, and (ii) on irrigation and hydroculture. These assets were recorded in “Accounts receivables”, set against “Revenue from Electric Energy Operations” (note 23).

In addition to the effects mentioned above, the other effects of the tariff adjustment for the subsidiary CPFL Paulista were:

• In order to review the PIS and COFINS amounts of the Generators, ANEEL recalculated the electric energy cost for the initial contracts related o the 2005’s tariff adjustment. As the cost of electric energy affects adjustment of the consumer tariff and calculation of CVA, the recalculation, which resulted in a reduction in the average energy price, generated a liability to be reimbursed to the consumers and an additional CVA asset. The CVA amounts approved by ANEEL in the 2007 Tariff Review Rate excluded the surpluses of the electric energy contracts, in accordance with item 61 of ANEEL Technical Note n° 069 of March 22, 2007. Accordingly, these effects basically explain the 2007 adjustments of R$ 98,635, recorded in “Other Accounts Payable”, and R$ 177,710, recorded in “Deferral of Tariff Costs”, both set against “Cost of Electric Energy” (note 24).

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• Also in connection with the events mentioned above, in the first quarter of 2007 the subsidiary CPFL Paulista recorded a reversal of R$ 10,910 in the PIS and COFINS - Generators pass-through regulatory asset and of R$ 15,834 in the Energy surpluses and shortfalls, estimated in accordance with ANEEL Technical Note n° 151/2006.

• Assets of R$ 14,854 were also recorded in 2007 in relation to other financial components of the 2007 IRT, relating mainly to R&D on the financial components of the 2004 to 2006 Tariff Review Rates, the Electric Energy for All (Luz para Todos) Program and others.

The following table shows the changes in the items described above in relation to Tariff Review and Adjustments, in the years ended December 31 2007 and 2006:

(1) The effects of provisions for constitution of the 2005 Tariff Adjustment were recorded in Operating Revenue (R$ 2,088), Deductions from Operating Revenue (R$ 16,236) and Operating Expense (R$ 3,302). In 2007, these effects of provisions were recorded in Operating Revenue (R$ 26,768), Cost of Energy (R$ 2,985), Operating Expense (R$ 2,006) and Financial Revenue (R$ 26). The effects of amortization were recorded in Operating Revenue R$ 39,212 (R$ 3,122 in 2006 and R$322 in 2005), Deductions from Operating Revenue (R$ 7,062 in 2006 and R$ 9,174 in 2005), Cost of Energy (R$ 677) and Operating Expense R$ 629 (R$ 2,096 in 2006 and R$1,207 in 2005).

(2) The effects of provisions for constitution of 2006 were recorded in Operating Revenue (R$ 9,030) in 2005 (R$22,958)and in Cost of Energy (R$ 31,492). The effects of amortization were recorded in Operating Revenue R$ 2,015 (R$ 11,534 in 2006 and R$ 11,424 in 2005) and Accounts Receivable R$ 15,116 (R$ 14,672 in 2006).

(3) The effects of provisions for constitution of 2006 were recorded in Operating Revenue (R$ 32,869) and in Cost of Energy (R$ 7,764). The effects of amortization were recorded in Operating Revenue R$ 15,385 (R$ 25,623 in 2006) and Accounts Payable (R$ 333) (R$ 11,456 in 2006 and R$ 11,502 in 2005).

c) Deferred Cost and Gain Variations (“CVA”)

Refer to the compensation mechanism defined by ANEEL, for the variations occurred in unmanageable costs incurred by electric power distribution utilities. These variations are calculated by the difference between the expenses effectively incurred and the expenses estimated at the time of composing the tariffs for the annual tariff increase adjustments.

The following expenses are currently considered unmanageable costs:

• Electric energy purchased (tariff for the electric energy purchased and Incentive Program for Alternatives to Electric Energy – “PROINFA”);
• Use of Transmission System Charges (tariff for the electric energy transmission from Itaipu Binacional, System Service Charges and usage tariff for the transmission installations forming the basic network);
• Quota of payment to the Fuel Consumption Account – CCC;
• Quota of payment to the Energy Development Account – CDE.

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The CVA amounts are restated based on the SELIC rate.

								Changes
		Balance  as of  December  31, 2006		Assets added  due to  acquisition of  equity interests								Balance  as of  December  31, 2007
										Monetary  restatement
						Deferral		Amortization
ASSET
Energy purchased		185,103		(3,651)		295,912		(296,766)		22,521		203,119
System service charge		37,526		5,310		(593)		(36,201)		1,718		7,760
Fuel Consumption Account - CCC		29,904		(2,605)		(11,572)		(12,234)		363		3,856
Energy Development Account - CDE		31,317		139		10,769		(31,563)		1,997		12,659
Total		283,850		(807)		294,516		(376,764)		26,599		227,394
LIABILITY
Energy purchased		(166,335)		(3,268)		(137,028)		120,909		(10,241)		(195,963)
System service charge		(54,431)		(251)		(3,480)		31,963		(2,891)		(29,090)
Fuel Consumption Account - CCC		(318)		(3,856)		(85,646)		37,646		(6,642)		(58,816)
Energy Development Account - CDE		-		(3)		-		8		(5)		-
Total		(221,084)		(7,378)		(226,154)		190,526		(19,779)		(283,869)

d) Low Income Consumers’ Subsidy

Law No. 10,438, of April 26, 2002, and Decree No. 4,336, of August 15, 2002, established new guidelines and criteria for the classification of consumer units in the low-income residential sub-class. This new methodology for calculating the subsidy established by ANEEL has been applied monthly since May 2002.

The amounts calculated using this methodology, after ratification by ANEEL, observe the following criteria for settlement:

• For the months in which losses by the concessionaire are calculated, the amounts should be reimbursed through granting of an economic subsidy by Eletrobrás (Governmental Institution), via the Energy Development Account (CDE).

• For the months in which gains by the concessionaire are calculated, the amounts should be reimbursed to the customer through a reduction in the annual tariff adjustments.

The changes in the balances in 2006 and 2007 are as follows:

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		Asset		Liability
Balances as of December 31, 2004		43,995		(5,175)
Gain (Loss) of revenue		20,729		(2,781)
Amortization of tariff adjustment		-		3,381
Amounts ratified by ANEEL		(17,541)		-
Monetary restatement		-		(825)
Balances as of December 31, 2005		47,183		(5,400)
Assets included due to acquisition of equity interest		1,389		(1,840)
Gain (Loss) of revenue		21,058		(1,357)
Amortization of tariff adjustment		-		4,134
Amounts ratified by ANEEL		(22,237)		-
Monetary restatement		-		(233)
Balances as of December 31, 2006		47,393		(4,696)
Assets included due to acquisition of equity interest		409		19
Gain (Loss) of revenue		17,413		(6,579)
Amortization of tariff adjustment		-		3,100
Amounts ratified by ANEEL		(9,198)		-
Monetary restatement		(50)		(468)
Balances as of December 31, 2007		55,967		(8,624)

4. CASH AND CASH EQUIVALENTS

		2007		2006
Bank deposits		679,937		259,359
Temporary cash investments		247,960		281,005
Total		927,897		540,364

Temporary cash investments represent transactions with Brazilian financial institutions, the majority of which earn interest according to the variation of the CDI, contracted under normal market conditions and interest rates, and are available for use in the operations of the Company and its subsidiaries.

5. FINANCIAL INVESTMENTS

The Company carries financial investments classified as “Held to maturity” and investment securities for trading, as follows:

- Held to maturity: In April 2005, through a Private Granting of Credit Agreement, the Company acquired the credit arising from the Purchase and Sale of Electricity Agreement between CESP — Companhia Energética de São Paulo (seller) and CPFL Brasil (purchaser), referring to the supply of energy for a period of 8 years. The amounts handed over by the Company to CESP will be settled using the funds arising from the acquisition of energy produced by that company for CPFL Brasil.

The Credit acquired by the Company earns interest of 17.5% p.a., plus the annual variation of the IGP-M. The balance as of December 31, 2007 is R$ 132,076 (R$ 132,516 in 2006), of which R$ 34,555 (R$ 28,615 in 2006) is classified as current assets.

- Investments for trading: The remaining balance in current assets in the amount of R$ 178,895 (R$ 89,886 in 2006) refers to debt security trading investments with maturities of over 90 days stated at fair value.

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6. ACCOUNTS RECEIVABLE

The balance, principally derived from electricity sales, is comprised as follows:

				Past-due		Past-due
				up to 90		over 90		Total
Consumer classes		Current		days		days		2007		2006
Current
Residential		237,773		161,046		26,400		425,219		371,145
Industrial		192,590		55,542		36,529		284,661		297,342
Commercial		107,093		46,332		28,562		181,987		173,588
Rural		31,816		7,523		1,615		40,954		35,262
Public administration		30,206		5,530		2,436		38,172		39,749
Public lighting		33,666		6,028		26,790		66,484		80,556
Public services		29,684		7,436		4,287		41,407		47,626
Billed		662,828		289,437		126,619		1,078,884		1,045,268
Unbilled		421,552		-		-		421,552		444,389
Financing of consumers’ debts (a)		30,146		2,443		8,271		40,860		78,213
Regulatory asset (note 3)		85,966		-		-		85,966		378,920
CCEE transactions (b)		38,876		-		-		38,876		19,793
Concessionaires and licensees (c)		74,529		11,149		4		85,682		76,939
Other		65,552		416		-		65,968		81,446
Total		1,379,449		303,445		134,894		1,817,788		2,124,968
Noncurrent
Financing of consumers’ debts (a)		152,549		-		-		152,549		101,930
CCEE transactions (b)		41,797		-		-		41,797		41,616
Regulatory asset (note 3)		20,668		-		-		20,668		21,364
Other		-		-		-		-		273
Total		215,014		-		-		215,014		165,183

a) Financing of consumers’ Debts

Refers to the negotiation of past-due accounts receivable from consumers, mainly public entities. In the case of public entities, some receivables are guaranteed by their ICMS collected (State VAT), which may be pledged through their bank accounts. Provisions are recognized for doubtful accounts based on the best estimates of the subsidiaries' managements for unsecured amounts and losses regarded as probable (Note 8).

b) CCEE transactions

These amounts refer to sales on the electricity spot market between distribution and generation companies that are settled by the CCEE, related to the period from September 2000 to December 2007. The noncurrent amount receivable mainly comprises: (i) legal adjustments, established as a result of suits brought by agents in the sector; (ii) lawsuits challenging the CCEE accounting for the period from September 2000 to December 2002; (iii) provisional accounting entries established by the CCEE; (iv) amounts negotiated bilaterally pending settlement. The Company considers that there is no significant risk on the realization of these assets and consequently no provision was posted in the accounts.

c) Concessionaries and licensees

Refers basically to balances receivable regarding the supply of electricity to other Concessionaires and Licensees by the subsidiaries CPFL Geração and CPFL Brasil, as well as for various transactions that have been set off, through a settlement of accounts, against amounts payable by the subsidiary CPFL Piratininga.

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7. ALLOWANCE FOR DOUBTFUL ACCOUNTS

The changes in the allowance for doubtful accounts during 2007, 2006 and 2005 are as follows:

Balance as of December 31, 2004		(50,420)
Additional allowance recorded		(91,918)
Recovery of assets		28,025
Write-off of accounts receivable		59,952
Balance as of December 31, 2005		(54,361)
Assets included due to acquisition of equity interests		(12,767)
Additional allowance recorded		(111,494)
Recovery of assets		28,170
Write-off of accounts receivable		50,843
Balance as of December 31, 2006		(99,609)
Assets included due to acquisition of equity interests (note 1)		(7,943)
Additional allowance recorded		(80,483)
Recovery of assets		32,949
Write-off of accounts receivable		59,447
Balance as of December 31, 2007		(95,639)

8. RECOVERABLE TAXES

The balances as of December 31, 2007 and 2006 are as follows:

		2007		2006
Current
Social contribution tax prepayments (CSLL)		8,653		4,020
Income tax prepayments (IRPJ)		10,051		7,219
Social contribution and income taxes credits		10,766		11,159
Withholding income tax (IRRF)		71,825		67,303
ICMS (state VAT)		64,221		43,820
PIS (tax on revenue)		2,457		5,994
COFINS (tax on revenue)		8,594		28,343
INSS (social security)		1,831		330
Other		3,356		2,765
Total		181,754		170,953
Noncurrent
Social contribution tax (CSLL)		24,966		22,846
Income tax (IRPJ)		840		9,477
PIS (tax on revenue)		3,044		3,898
COFINS (tax on revenue)		859		6,588
ICMS (state VAT)		69,508		60,240
Other		730		-
Total		99,947		103,049

In noncurrent assets, the balance of “Social Contribution Tax” refers to the final favorable outcome in a lawsuit brought by the subsidiary CPFL Paulista in 2004. The subsidiary CPFL Paulista is still awaiting the result of administrative proceedings in the Federal Revenue Service regarding the offset of the credit.

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9. PREPAID EXPENSES

		Current				Noncurrent
		2007		2006		2007		2006
Regulatory asset (note 3)		183,979		178,082		28,647		19,398
Other		18,742		13,157		14,464		9,371
Total		202,721		191,239		43,111		28,769

10.DEFERRED TAXES

Composition of deferred income and social contribution taxes:

		2007		2006
Social contribution tax:
Tax loss carryforwards		34,637		45,557
Tax benefit on merged goodwill		234,114		169,809
Temporarily nondeductible differences		68,001		74,983
Subtotal		336,752		290,349
Income tax:
Tax loss carryforwards		83,092		101,300
Tax benefit on merged goodwill		714,041		490,722
Temporarily nondeductible differences		198,576		212,986
Subtotal		995,709		805,008
Other		-		2,190
Total		1,332,461		1,097,547
Current assets		168,485		188,942
Noncurrent assets		1,163,976		908,605
Total		1,332,461		1,097,547

The expected recovery of the deferred tax credits derived from tax loss carryforwards, temporary nondeductible differences and tax benefit on merged goodwill are based on projections of future income prepared by the Company and its subsidiaries, which are examined by the Fiscal Council and approved by the Boards of Directors.

The tax benefit on merged goodwill refers to the tax credit calculated based on the merged goodwill arising from acquisitions, recorded in accordance with CVM Instructions No. 319/1999 and No. 349/2001. The tax benefit have been realized proportionately to the merged goodwill amortization, in accordance with the net projected income of the subsidiaries during the remaining term of its concession.

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Temporarily nondeductible differences are as follows:

		Social contribution tax				Income tax
		(CSLL)				(IRPJ)
		2007		2006		2007		2006
Reserve for contingencies		12,262		13,028		44,745		39,350
Post-retirement benefit obligation		5,914		7,566		17,425		22,011
Allowance for doubtful accounts		8,883		9,349		24,672		27,587
Provision for losses on realization of RTE		404		10,195		1,121		28,317
Research and development and energy efficiency
programs		14,000		8,457		38,888		23,491
Regulatory liability – increase in PIS and COFINS		8,105		2,776		22,512		7,710
Profit sharing		1,604		3,290		5,138		9,821
Differences in depreciation rates due to property,
plant and equipment revaluation		11,109		10,053		30,859		27,925
Other		5,720		10,269		13,216		26,774
Total		68,001		74,983		198,576		212,986

Reconciliation of income and social contribution taxes, reported in the statement of income for the years ended December 31, 2007, 2006 and 2005 are as follows:

		2007				2006				2005
		Social				Social				Social
		contribution		Income tax		contribution		Income tax		contribution		Income tax
		tax (CSLL)		(IRPJ)		tax (CSLL)		(IRPJ)		tax (CSLL)		(IRPJ)
Income before taxes		2,476,655		2,476,655		2,171,091		2,171,091		1,430,541		1,430,541
Statutory tax rates		9%		25%		9%		25%		9%		25%
Tax expense at statutory tax rates		(222,899)		(619,164)		(195,398)		(542,773)		(128,749)		(357,635)
Nondeductible goodwill amortization		(7,817)		(35,912)		(5,640)		(34,720)		(5,503)		(29,390)
Nondeductible supplementary monetary
restatement		(1,602)		-		(1,721)		-		(2,185)		-
Nondeductible pension income		-		-		-		-		5,540		15,390
Realization (accrual) of allowance for
loss on Investment		-		-		(15)		(41)		11,982		33,282
Dividends received from noncontrolling
investments		8		22		420		1,167		831		2,308
Differences in depreciation rates due to
property, plant and equipment
revaluation		-		-		5,330		14,805		(1,501)		(4,170)
Effect of presumed profit system		2,880		10,330		-		-		-		-
Interest on shareholders’ equity		13		35		-		-		17,150		47,638
Other additions/deductions, net		(3,542)		(4,189)		(494)		(2,283)		(1,836)		(2,864)
Subtotal tax expense		(232,959)		(648,878)		(197,518)		(563,845)		(104,271)		(295,441)
Tax credit allocated		486		53,326		9,700		17,400		11,899		51,480
Total Tax expense		(232,473)		(595,552)		(187,818)		(546,445)		(92,372)		(243,961)
Current tax expense		(202,083)		(560,363)		(172,998)		(477,036)		(101,787)		(287,008)
Deferred tax expense		(30,390)		(35,189)		(14,820)		(69,409)		9,415		43,047

The “non-deductible goodwill amortization” refers to the amortized goodwill from the investees, which is nondeductible for tax purposes.

“Differences in depreciation rates due to property, plant and equipment revaluation” - refers mainly to the difference between the depreciation rate used by the subsidiary RGE, as a result of the revaluation of assets and that applied to the equity. The lower depreciation of the subsidiary RGE generates additional income and social contribution taxes, and beginning 2006, these taxes have been deferred in the consolidated financial statements.

F - 30

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“Effect of presumed profit system” – Refers to the effect of a different income tax methodology, used to register and collect income taxes and social contribution to a specific subsidiary, in 2007.

“Realization of allowance for loss on investment” — in 2005, RGE disposed of its subsidiary Sul Geradora Participações, and accordingly the previously established provision for loss on investment became deductible.

“Tax Credit Allocated” refers to the tax benefit on the goodwill as consequence of Semesa’s merger by CPFL Geração, as described in note 1, and tax credit on tax loss carryforwards based on expectations of income and social contribution taxes payable in the future.

11.OTHER

The composition of the balance is as follows:

		Current				Noncurrent
		2007		2006		2007		2006
Receivables from CESP (a)		18,277		22,121		27,204		54,727
Advances - Fundação CESP		5,732		5,046		-		-
Pledges, funds and tied deposits (b)		3,137		6,208		139,181		71,113
Receivables from BAESA’s shaheholders (c)		-		16,755		31,794		-
Orders in progress		19,018		8,706		-		5,266
Services rendered to third parties		19,979		22,122		-		10
Reimbursement RGR		3,340		3,267		707		545
Advance energy purchase agreements		8,129		2,918		29,845		1,600
Other		33,740		22,866		3,089		8,796
Total		111,352		110,009		231,820		142,057

a) Receivables from CESP: Refers to receivables from CESP by the subsidiary CPFL Paulista, arising from settlements made through the distribution concessionaires of São Paulo in 1993. The balance is monetarily restated according to the variation of the US dollar, plus interest calculated on 50% of quarterly Libor and a spread of 0.40625% p.a., through two installments per year with final maturity in December 2009.

b) Pledges, funds and tied deposits: Refers mainly to guarantees (i) offered when loans were negotiated, and (ii) to suport CCEE transactions;

c) Receivables from BAESA’s shareholders: Differentiated rights to BAESA's net income were recognized as of December 31, 2006, in accordance with a shareholders' agreement, as equity in subsidiaries, at a different percentage from that of CPFL Geração's participation in the venture. However, in 2007, as a result of negotiation between the shareholders, it was agreed that CPFL Geração's right to the differentiated net income will be realized by settlement between the shareholders. In 2007, the amount was recorded in the statement of income as “Other Operating Income”.

F - 31

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12. PROPERTY, PLANT AND EQUIPMENT

As of December 31, 2007 and 2006, the composition of Property, plant and equipment is as follows:

				2007						2006
						Accumulated
						Depreciation
		Depreciation				and
		rate (%)		Cost		Amortization		Net		Net
In Service:
Distribution				7,555,228		(3,835,444)		3,719,784		3,288,325
Intangible assets (a)		20		154,913		(58,268)		96,645		99,494
Land				52,464		-		52,464		50,184
Buildings, constructions and improvements		2 and 4		184,821		(107,543)		77,278		77,625
Machinery and equipment		2 to 10		7,058,769		(3,597,707)		3,461,062		3,036,062
Vehicles		10 and 20		72,865		(53,536)		19,329		13,779
Furniture and fixtures		10		31,396		(18,390)		13,006		11,181
Generation				1,499,460		(154,042)		1,345,418		668,944
Intangible assets (a)		20		2,315		(350)		1,965		1,656
Land				15,394		-		15,394		12,035
Reservoirs and dams		2 to 5		722,829		(44,822)		678,007		248,523
Buildings, constructions and improvements		2 and 4		232,663		(36,144)		196,519		123,718
Machinery and equipment		2 to 10		522,515		(70,964)		451,551		281,434
Vehicles		10 and 20		1,352		(661)		691		828
Furniture and fixtures		10		2,392		(1,101)		1,291		750
Commercialization				207,926		(79,261)		128,665		103,987
Intangible assets (a)		20		13,881		(5,830)		8,051		5,826
Land				152		-		152		120
Buildings, constructions and improvements		2 and 4		12,674		(9,445)		3,229		2,487
Machinery and equipment		2 to 10		170,162		(58,821)		111,341		91,445
Vehicles		10 and 20		4,236		(2,432)		1,804		1,285
Furniture and fixtures		10		6,821		(2,733)		4,088		2,824
Administration				231,479		(149,464)		82,015		69,854
Intangibles assets (a)		20		90,531		(60,795)		29,736		24,379
Land				2,545		-		2,545		2,197
Buildings, constructions and  improvements		2 and 4		47,765		(26,089)		21,676		18,406
Machinery and equipment		2 to 10		43,879		(29,884)		13,995		12,057
Vehicles		10 and 20		6,629		(4,706)		1,923		1,395
Furniture and fixtures		10		40,130		(27,990)		12,140		11,420
Subtotal				9,494,093		(4,218,211)		5,275,882		4,131,110

(a) refers mainly to softwares and rights of way.

continues

F - 32

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				2007						2006
						Accumulated
						Depreciation
		Depreciation				and
		rate (%)		Cost		Amortization		Net		Net
								(Continued)
In Progress
Distribution				284,420		-		284,420		250,828
Generation				802,857		-		802,857		1,072,026
Commercialization				13,966		-		13,966		17,328
Administration				36,078		-		36,078		21,469
Subtotal				1,137,321		-		1,137,321		1,361,651
Assets leased to third parties
Land				4,676		-		4,676		4,675
Reservoirs and dams		2		105,853		(20,532)		85,321		86,812
Buildings, constructions and improvements		3.83		523,062		(110,328)		412,734		424,209
Machinery and equipment		5.93		306,795		(87,485)		219,310		228,562
Vehicles		20		92		(92)		-		-
Other		20		91		(38)		53		62
Subtotal				940,569		(218,475)		722,094		744,320
Subtotal				11,571,983		(4,436,686)		7,135,297		6,237,081
Other assets not linked to the concession				6,905		(2,532)		4,373		-
Total Property, plant and equipment .				11,578,888		(4,439,218)		7,139,670		6,237,081
Special obligations								(919,097)		(791,387)
Property, plant and equipment, net								6,220,573		5,445,694

The assets and installations used in the generation, transmission, distribution and sale of electric energy are linked to these services and cannot be retired, sold or pledged as mortgage guarantees without the prior and express authorization of ANEEL, which regulates the electric energy utility concession assets, giving prior authorization for not restricting assets not linked to the concession, when intended for sale, and determining that the proceeds from the sale be deposited in a restricted bank account, and invested in the concession.

The average depreciation rate of property, plant and equipment is approximately 5.0% per year for distributors and 2.6% per year for generators.

Fixed assets in progress - Of the balance as of December 31, 2007, R$ 779,154 refers to projects in the construction stage, as follows:

								FOZ DO
		CERAN		ENERCAN		BAESA		CHAPECÓ		TOTAL
Plant under construction as of
December 31, 2007		731,512		80,575		2,065		517,440		1,331,592
Company’s proportionate share
in each plant		475,484		39,260		516		263,894		779,154

The interest corresponding to the loans taken by these projects to finance the construction is being capitalized. In 2007, 2006 and 2005 the Company capitalized interest amounting to R$ 28,976, R$ 53,630 and R$ 53,757, respectively.

F - 33

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Assets leased to third parties - These assets relate mainly to the Serra da Mesa power plant. The concession to operate this plant is held by Furnas. Pursuant to a lease contract, the Company constructed part of the plant and subsequently leased it to the concessionaire for a period of 30 years, ending in 2028 (the “Serra da Mesa Lease”). The lease agreement gives the Company the right to 51.54% of the total assured energy sold by the plant. The Company has entered into a 15-year contract to sell this energy to Furnas. The contract provides for an initial price per MWh, which is adjusted based on the IGP-M. The sales contract expires in 2014.

Special obligations - Special obligations linked to electric energy utility concession represent amounts received principally from the Federal, State and Municipal Governments, and consumers to be invested in the Company’s property, plant and equipment. In accordance with ANEEL Resolution No.234/2006, which establishes the principles for holding the second cycle of the periodic tariff review, each distribution subsidiary is or will commence amortizing its special obligations prospectively, using the depreciation rates applied for depreciation of the Property, plant and equipment.

Public Utilities - Upon signing their respective Concession Agreements, the subsidiaries CERAN, ENERCAN, BAESA, Foz do Chapecó and Paulista Lajeado assumed obligations with the Federal Government in relation to the granting of the concession, due from the 7th or 8th to the 35th year of the concession, as “ Public Utilities”, adjusted annualy based on inflation (IGP-M). The balances as of December 31, 2007, are as follows:

		Annual amount				Total amount				Payment
				CPFL				CPFL
		Total		Energia's		Total		Energia's		Number of		Begin		Final
Companies				interest				interest		Parcel
CERAN		5,780		3,757		167,620		108,953		348		March/2007		February/2036
ENERCAN		1,511		736		42,938		20,920		341		June/2006		October/2034
BAESA		16,511		4,129		478,819		119,733		348		June/2007		May/2036
Foz do Chapecó		33,344		17,005		933,632		476,152		336		December/2008		November/2036
Paulista Lajeado		226		122		7,220		3,901		348		January/2004		January/2033
TOTAL		57,372		25,749		1,630,229		(729,659)

The subsidiaries record the concession amounts in expenses, upon the payments, according to realization.

F - 34

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13.GOODWILL

The composition of the goodwill account is as follows:

		2007						2006
		Historical		Accumulated						Amortization
		Cost		Amortization		Net Value		Net Value		Rate - 2007
Goodwill on acquisition
Parent company
CPFL Paulista		292,033		(38,708)		253,325		273,669		6.63%
CPFL Piratininga		39,065		(4,830)		34,235		36,690		6.25%
CPFL Geração		54,555		(8,036)		46,519		49,867		6.17%
RGE (note 1)		3,150		-		3,150		-		0.00%
Other		26		-		26		-
		388,829		(51,574)		337,255		360,226
Subsidiaries
CPFL Jaguariúna (note 1)		142,793		(5,116)		137,677		-		4.18%
ENERCAN		10,233		(419)		9,814		10,233		4.10%
Barra Grande		3,081		(445)		2,636		2,858		7.18%
Foz do Chapecó		7,319		-		7,319		7,319		0.00%
RGE (acquisition through CPFL
Paulista)		-		-		-		495,712		0.00%
RGE (acquisition through DOC3)		1,120,266		(677,599)		442,667		461,169		3.67%
CPFL Santa Cruz		-		-		-		111,794		0.00%
CPFL Geração (Semesa)		426,450		(171,550)		254,900		269,058		5.26%
Other		17,518		(9,239)		8,279		90		4.99% to 12.12%
		1,727,660		(864,368)		863,292		1,358,233
Subtotal		2,116,489		(915,942)		1,200,547		1,718,459
Goodwil reassessment
Parent company
CPFL Paulista		1,074,026		(216,391)		857,635		922,734		6.63%
CPFL Piratininga		115,762		(14,314)		101,448		108,720		6.25%
RGE		310,127		(10,717)		299,410		56,730		3.06%
CPFL Santa Cruz		61,685		(2,715)		58,970		-		4.40%
		1,561,600		(244,137)		1,317,463		1,088,184
Subsidiaries
CPFL Leste Paulista		21,131		(6,729)		14,402		-		8.38%
CPFL Sul Paulista		20,941		(6,834)		14,107		-		8.44%
CPFL Jaguari		20,026		(6,558)		13,468		-		8.43%
CPFL Mococa		8,444		(2,748)		5,696		-		8.48%
		70,542		(22,869)		47,673		-
Subtotal		1,632,142		(267,006)		1,365,136		1,088,184
Total		3,748,631		(1,182,948)		2,565,683		2,806,643

The goodwill is amortized proportionately to the projected net income for the remaining term of the concession contract of each investee, as required by ANEEL, and is subject to periodic review.

Goodwill reassessment

In order to streamline these investments financially and administratively, a sequence of corporate restructuring measures occurred and some subsidiaries were merged by its investees. Those mergers were registered following CVM Instructions No. 319/1999 and No. 349/2001, resulting in the reclassification of the tax benefit arising from goodwill to Deferred Taxes Credits (note 10). Those mergers also impact the investment recorded by the Parent Company that must recompose its equity investment through a goodwill reassessment. Those transaction avoid the negative impact on dividends paid arising from goodwill amortization to the Parent Company.

F - 35

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14.SUPPLIERS

As of December 31, 2007 e 2006, the balance is as follows:

		2007		2006
Current
System service charges		6,126		14,283
Energy purchased		572,498		515,103
Electricity network usage charges		94,931		75,131
Materials and services		148,174		132,604
Co-generation		5,559		4,224
Free energy (note 3)		35,609		103,581
Other		5,057		9,235
Total		867,954		854,161
Long-Term
Free energy (note 3)		223		-

15. TAXES AND PAYROLL CHARGES PAYABLE

As of December 31, 2007 and 2006, the balance is as follows:

		Current				Long-term
		2007		2006		2007		2006
ICMS (State VAT)		294,760		282,510		-		-
PIS (Tax on revenue)		11,668		11,368		-		838
COFINS (Tax on revenue)		52,910		49,286		249		3,862
IRPJ (Corporate income tax)		186,480		122,313		12,140		25,765
CSLL (Social contribution tax)		39,846		39,854		4,140		9,276
Other		18,429		17,427		-		-
Total		604,093		522,758		16,529		39,741

F - 36

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16.INTEREST, LOANS AND FINANCING

The composition is as follows:

		2007								2006
		Interest								Interest
		Current								Current
		and Long								and Long-
LOCAL CURRENCY		term		Current		Long-term		Total		term		Current		Long-term		Total
BNDES — Repowering
(PCHs)		124		7,057		26,521		33,702		161		4,104		23,813		28,078
BNDES — Investment		6,164		237,672		1,637,143		1,880,979		10,995		203,374		1,251,703		1,466,072
BNDES — Parcel “A”, RTE and Free energy		663		142,216		-		142,879		787		338,163		124,369		463,319
BNDES — Purchase of assets		16		-		869		885		-		-		-		-
Credit Rights Investment
Fund (FIDC)		-		-		-		-		7,086		4,953		-		12,039
Furnas Centrais Eletricas S.A.		-		47,519		111,665		159,184		-		-		124,404		124,404
Financial institutions		45,418		233,752		143,032		422,202		4,788		13,915		304,829		323,532
Other		607		28,913		26,416		55,936		548		34,349		21,127		56,024
Subtotal		52,992		697,129		1,945,646		2,695,767		24,365		598,858		1,850,245		2,473,468
FOREIGN CURRENCY
IDB		669		3,133		59,394		63,196		886		2,656		75,472		79,014
Financial institutions		31,531		162,443		860,064		1,054,038		7,158		56,602		547,281		611,041
Subtotal		32,200		165,576		919,458		1,117,234		8,044		59,258		622,753		690,055
Total		85,192		862,705		2,865,104		3,813,001		32,409		658,116		2,472,998		3,163,523

F - 37

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		As of December 31
LOCAL CURRENCY		2007		2006		Remuneration		Amortization		Guarantees
BNDES - Power Increases (PCH’s)
CPFL Geração		5,022		7,410		TJLP + 3.5% p.a.		84 monthly installments beginning February 2003		Guarantee of CPFL Paulista
CPFL Geração		248		442		UMBND + 3.5% p.a.		84 monthly installments beginning February 2003		Guarantee of CPFL Paulista
CPFL Geração		28,080		19,644		TJLP + 3.1% to 4.3% p.a.		monthly installments beginning September 2004		Guarantee of CPFL Energia
CPFL Geração		352		582		UMBND + 4% p.a.		72 monthly installments beginning September 2004		Guarantee of CPFL Energia
BNDES – Investment
CPFL Paulista — FINEM I		1,700		13,259		TJLP + 3.25% p.a.		78 monthly installments beginning October 2000 and October 2001		Revenue
CPFL Paulista — FINEM II		190,161		257,040		TJLP + 5.4% p.a.		48 monthly installments beginning January 2007		Guarantee of CPFL Energia and receivables
CPFL Paulista — FINEM III		125,574		-		TJLP + 3.3%		72 monthly installments beginning Janury 2008		Guarantee of CPFL Energia and receivables
RGE — FINEM I		136,740		136,542		TJLP + 3.5% to 5.0% p.a.		monthly installments beginning October 2000 to December 2012		Revenue / Reserve Account / Promissory notes
RGE — FINEM II		4,062		9,390		UMBND + 4.5% p.a. (1)		36 monthly installments beginning February 2006		Revenue collection/reserve account
CPFL Piratinga — FINEM I		70,808		95,718		TJLP + 5.4% p.a.		48 monthly installments beginning January 2007		Guarantee of CPFL Energia and receivables
CPFL Piratinga — FINEM II		87,937		-		TJLP + 3.3% p.a.		72 monthly installments beginning January 2008		Guarantee of CPFL Energia and receivables
BAESA		166,751		181,797		TJLP + 3.125% p.a.		144 monthly installments beginning September 2006 and November 2006		Letters of Credit
BAESA		34,725		45,659		UMBND + 3.125% p.a.		144 monthly installments beginning November 2006		Letters of Credit
ENERCAN		372,079		389,214		TJLP + 4% p.a.		144 monthly installments beginning April 2007		Letters of Credit
ENERCAN		22,688		28,845		UMBND + 4% p.a.		144 monthly installments beginning April 2007		Letters of Credit
CERAN		277,903		261,797		TJLP + 5% p.a.		168 monthly installments beginning December 2005		Guarantee of CPFL Energia
CERAN		40,703		46,811		UMBND + 5% p.a. (2)		168 monthly installments beginning February 2006		Guarantee of CPFL Energia
CERAN		104,116		-		TJLP + 3.3% to 4.3% p.a.		168 monthly installments beginning November 2008		Guarantee of CPFL Energia
Foz do Chapecó		245,032		-		TJLP + 2.49% to 2.95% p.a.		192 monthly installments beginning October 2011		Pledge of shares, credit rights and income
BNDES — Parcel “A”, RTE and Free energy
CPFL Paulista — RTE		-		52,593		Selic + 1% p.a.		62 monthly installments beginning March 2002		Receivables
CPFL Paulista — Parcel “A”		139,760		332,938		Selic + 1% p.a.		13 monthly installments beginning May 2007		Receivables
CPFL Piratininga — Parcel “A”		-		67,031		Selic + 1% p.a.		9 monthly installments beginning September 2007		Receivables
CPFL Santa Cruz - RTE		-		5,166		Selic + 1% p.a.		65 monthly installments beginning March 2002		Revenue
CPFL Sul Paulista - RTE		2,267		-		Selic + 1% p.a.		79 monthly installments beginning March 2002		Receivables
RGE — Free Energy		494		3,251		Selic + 1% p.a.		60 monthly installments beginning March 2003		Receivables
CPFL Geração— Free Energy		358		2,340		Selic + 1% p.a.		60 monthly installments beginning March 2003		Guarantee of CPFL Paulista
BNDES — Purchase of assets
CPFL Brasil		885		-		TJLP + 2.84% p.a.		36 monthly installments beginning May 2009		Linked to the acquired asset
FIDC — CPFL Piratininga		-		12,039		112% of CDI		36 monthly installments beginning March 2004		Receivables
Furnas Centrais Eletricas S.A.
CPFL Geração		159,184		124,404		IGP-M + 10% p.a.		24 monthly installments beginning August 2008		Energy produced by plant
Financial institutions
CPFL Paulista
Banco do Brasil- Law 8727		49,675		52,341		Variation of IGPM +7.42% p.a.		240 monthly installments beginning May 1994		Receivables
RGE
Banco Itau BBA		103,425		104,243		106% of CDI		1 installment in March 2011		No guarantee
Banco Santander I		-		7,946		105% of CDI		7 quarterly installments beginning January 2006		Promissory notes
Banco Santander II		57,690		51,332		104.5% of CDI		1 installment in January 2008		No guarantee
Banco ABN AMRO Real		84,419		73,450		107.5% of CDI (3)		2 installment in January 2008 and 1 installment in February 2008		No guarantee
Banco do Brasil		38,481		34,220		105% of CDI		1 installment from January 2008		No guarantee
Foz de Chapecó
Banco Bradesco		88,512		-		104.6% CDI, 106.8% CDI and 107.6% CDI		1 installment in January 2008		No guarantee
Other
ELETROBRAS
CPFL Paulista		11,369		10,082		RGR + rate variable of 6% to 9% p.a.		120 monthly installments beginning August 2006		Receivables/Promissory notes
CPFL Piratininga		2,444		5,971		5% p.a.		120 Monthly installments beginning August 2006		Receivables/Promissory notes
RGE		5,183		5,493		RGR + rate of 6% to 6.5% p.a.		120 Monthly installments beginning August 2004		Revenue/Promissory notes
CPFL Santa Cruz		6,764		6,578		5%. p.a.		100 to 120 monthly installments beginning December 2002		Revenues
CPFL Leste Paulista		1,250		-		5% to 9% p.a.		120 Monthly installments beginning February 2008		Revenues
CPFL Sul Paulista		1,892		-		5% to 9% p.a.		120 Monthly installments beginning August 2007		Revenues
CPFL Jaguari		39		-		5% to 9% p.a.		120 Monthly installments beginning June 2007		Revenues
CPFL Mococa		356		-		5% to 9% p.a.		120 Monthly installments beginning January 2008		Revenues
Other		26,639		27,900
Total tocal currency		2,695,767		2,473,468

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		As of December 31,
FOREIGN CURRENCY		2007		2006		Remuneration		Amortization		Collateral
IDB — Enercan		63,196		79,014		US$ + Libor + 3.5% p.a.		49 quarterly installments beginning June 2007		Guarantee of CPFL Energia
Financial institutions
Parent company
Banco do Brasil		183,756		8,406		Yen + 5.7778% p.a. (4)		1 installment in September 2009		No guarantees
CPFL Paulista
Debt Conversion Bond		9,610		14,174		US$ + 6-month Libor + 0.875% p.a.		17 semiannual installments beginning April 2004		Revenue/Government SP guarantee
New Money Bond		845		1,700		US$ +6-month Libor + 0.875% p.a.		17 semiannual installments beginning April 2001		Revenue/Government SP guarantee
FLIRB		857		1,724		US$ + 6-month Libor + 0.8125% p.a.		13 semiannual installments beginning April 2003		Revenue/Government SP guarantee
C-Bond		12,434		17,316		US$ + 8% p.a.		21 semiannual installments beginning April 2004		Revenue/Government SP guarantee
Discount Bond		15,650		18,884		US$ + 6-month Libor +0.8125%p.a.		1 installment inApril 2024		Escrow deposits and revenue Gov.SP guarantee
PAR-Bond		22,412		27,052		US$ + 6% p.a.		1 installment in April 2024		Escrow deposits and revenue Gov.SP guarantee
Banco do Brasil		83,139		156,707		Yen + 5.7778% p.a. (4)		1 installment in September 2009		No guarantee
ABN AMRO Real		327,002		-		Yen + 1.4824% p.a.(5)		1 installment in August 2009		No guarantee
RGE – Banco do Brasil		27,140		-		Yen + 5.7778% p.a. (4)		1 installment in September 2009		No guarantee
Nova 4 - Banco do Brasil		-		196,922		Yen + 5.7778% p.a. (4)		1 installment in September 2009		No guarantee
CPFL Geração - Banco do Brasil		308,742		153,444		Yen + 2.5% to 5.8% p.a. (6)		1 installment between February 2008 and April 2010		Guarantee of CPFL Energia
Enercan - Banco Itaú BBA		-		14,712		US$ + Libor + 14.5% (7)		1 installment in July 2007		No guarantee
Foz do Chapecó - Bradesco		62,451		-		US$+6.5% and 3.99% p.a. (8)		1 installment in January 2008		No guarantee
Total foreign currency		1,117,234		690,055
Total		3,813,001		3,163,523

The Company and its subsdiaries hold swap converting the local cost of currency variation to interest tax variation in reais, corresponding to
(1) 119.0%, 134.45 and 135.0% of CDI		(4) 103.5% of CDI		(7) 109.5% of CDI
(2) Balance of R$ 16,673 of 2006, Swap of 138.43% of CDI		(5) 102.9% of CDI		(8) 104.6% of CDI
(3) Pre fixed interest from 14% to 15.19%		(6) 103.25% up to 104.2% of CDI

Main funding:

Local currency

BNDES - Investiment (CPFL Paulista - FINEM III) - The subsidiary obtained approval for financing of R$ 156,543 from Banco Nacional de Desenvolvimento Econômico e Social (“BNDES”) in 2007, as part of a FINEM credit line, to be invested in the expansion and modernization of the Electric Energy System. The subsidiary received R$ 125,011 during the year and the balance of R$ 31,532 is scheduled for release in 2008. The interest is paid quarterly and as from January 15, 2008 the payments will be made monthly.

BNDES - Investiment (CPFL Piratininga - FINEM II) – The subsidiary CPFL Piratininga obtained approval for financing of R$ 121,574 from BNDES in 2007, as part of a FINEM credit line, to be invested in the expansion and modernization of the Electric Energy System. By December 31, 2007 the subsidiary had received R$ 87,516 and the balance of R$ 34,058 is scheduled for release in 2008. The interest is paid quarterly and as from January 15, 2008 the payments will be made monthly.

BNDES - Investiment (CERAN) – Further installments of the loan from the BNDES contracted in February 2004 to finance Castro Alves and 14 de Julho projects, amounting to R$ 161,502 (R$ 104,976 in proportion to the participation of the subsidiary CPFL Geração), were released in 2007.

BNDES - Investiment (Foz do Chapecó) – In 2007, the Board of Directors of BNDES authorized the granting of credits in the amount of R$ 1,655,838 to the subsidiary Foz do Chapecó, to finance the construction of Foz do Chapecó Hydropower Plant. In 2007, R$ 480,000 was released (R$ 244,800 in proportion to CPFL Geração’s equity interest). To honor commitments assumed prior to release of BNDES funds, short-term loans of R$ 296,230 (R$ 151,077 in proportion to CPFL Geração’s equity interest) were taken out with financial institutions.

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Foreign currency

Financial institution (CPFL Paulista) – The subsidiary contracted a foreign currency loan from ABN AMRO REAL in August 2007, amounting to R$ 360,000, in order to make the escrow deposit mentioned in Note 20.

Financial institution (RGE) – In 2007 the subsidiary contracted a loan of R$ 27,053 from Banco do Brasil, in order to finance working capital requirements.

Financial institution (CPFL Geração) – the subsidiary contracted credit lines from Banco do Brasil, to honor short-term commitments of R$ 177,700, maturing between February 2008 and April 2010. The interest will be paid together with the principal between February 2008 and April 2010.

Financial institutions (Parent Company) – refers to the loan of R$ 200,000 contracted in 2006 from the Banco do Brasil, for acquisition of a share in the indirect subsidiary CPFL Santa Cruz. The principal and interest mature in September 2009. In 2007, the Company assumed the loan in the course of assumption of the subsidiary's debt.

Maturity of loans and financing

As of December 31, 2007, the maturities of the long-term portion of loans and financing are as follows:

Indices

The main indices used to monetarily restate Loans and Financing and the composition of the indebtedness profile in local currency are stated below:

Index		Accumulated Variation in %				Debt Composition %
		2007		2006		2007		2006
IGP-M (General Price Index – Market)		7.75		3.83		7.75		7.15
UMBND (BNDES basket of currencies)		(16.78)		(8.52)		3.81		4.95
TJLP (Long-term Interest Rate)		6.38		7.87		67.25		55.15
CDI (Interbank Deposit Certificate)		11.82		15.03		13.82		11.45
SELIC		11.85		15.07		5.30		18.73
Other		-		-		2.07		2.57
						100.00		100.00

SWAP OPERATIONS

The gains and losses on the swap operations made by the Company and its subsidiaries, including contracting on short-term operations, are recorded in the balance sheet, under Derivatives, and corresponding amounts are recognized under financial income or expense (see note 31.2) . These operations as of December 31, 2007, resulted in a net liability of R$ 175,744 (liability of R$ 74,758 as of December 31, 2006).

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Restrictive covenants

Loans and financing contracts with BNDES establishes restrictions to the subsidiaries CPFL Paulista, CPFL Piratininga and RGE to: (i) not realize payments of dividends and interest on equity totaling more than the minimum mandatory dividend laid down by law without prior agreement of the BNDES, and the lead bank in the operation; (ii) totally accomplish with the restrictive conditions established by the contract. In adition, certain loans and financing agreements are subject to certain restrictive covenants and include clauses that require the Company and its subsidiaries to maintain certain financial ratios within predefined parameters as follows:

CPFL Paulista:

BNDES - FINEM I – (Lead bank: BRADESCO)

• Net indebtedness divided by EBITDA – maximum of 3.0 from 2007 to 2008;

• Net indebtedness divided by the sum of net indebtedness and net equity – maximum of 0.80 in 2007 and 2008.

BNDES - FINEM II – (Lead bank: UNIBANCO)

• Net indebtedness divided by EBITDA – maximum of 3.0 from 2007 to 2010.

• Net indebtedness divided by the sum of net indebtedness and net equity – maximum of 0.80 in 2007 and 2008 and 0.75 from 2009 to 2010.

BNDES - FINEM III – (Lead bank: BANK OF BRASIL)

• Net indebtedness divided by EBITDA – maximum of 3.0 from 2007 to 2013.

• Net indebtedness divided by the sum of net indebtedness and net equity – maximum of 0.80 in 2007 and 2008 and 0.75 from 2009 to 2013.

CPFL Piratininga:

BNDES - FINEM I – (Lead bank: UNIBANCO)

• Net indebtedness divided by EBITDA – maximum of 2.5 in 2007, 3.0 in 2008 and 2.5 in 2009 to 2010.

• Net indebtedness divided by the sum of net indebtedness and net equity – maximum of 0.80 from 2007 to 2010.

BNDES - FINEM II – (Lead bank: BANCO DO BRASIL)

• Net indebtedness divided by EBITDA – maximum of 2.5 in 2007, 3.0 in 2008 and 2.5 from 2009 to 2013.

• Net indebtedness divided by the sum of net indebtedness and net equity – maximum of 0.80 from 2007 to 2013.

RGE:

BNDES - FINEM I (Lead bank: Caixa Econômica Federal)

• Net indebtedness divided by EBITDA – less or equal to 3.0.

• Net indebtedness divided by the sum of net indebtedness and net equity – less or equal to 0.5.

BNDES - FINEM II - (Lead bank: UNIBANCO)

• Net indebtedness divided by EBITDA – less or equal to 2.5.

• Net indebtedness divided by the sum of net indebtedness and net equity – less or equal to 0.5.

Itaú BBA Bank - Contains restrictive clauses in relation to amendment or changes to the Capital, and any direct or indirect change, transfer or assignment of the share control, or merger, amalgamation or spin-off, without the prior and express agreement of the creditor. The following financial ratios must also be maintained:

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• EBITDA divided by net financial expenses - higher or equal to 1.6;

• Net financial indebtedness divided by EBITDA – less or equal to 2.7.

ABN AMRO Real Bank - Requires compliance with the following financial ratios:

• Total indebtedness divided by EBITDA - less or equal to 3.0;

• Interest coverage – higher or equal to 2.0;

• Maximum total indebtedness divided by Capitalization – less or equal to 0.55.

CPFL Geração:

The loans raised from the BNDES by the indirect jointly-controlled subsidiaries ENERCAN, BAESA, CERAN and Foz do Chapecó, establish restrictions on the payment of dividends to the subsidiary CPFL Geração higher than the minimum mandatory dividend of 25% without the prior agreement of the BNDES.

ENERCAN's loan from BNDES and IDB establishes restrictive clauses that require the subsidiary to maintain certain financial ratios within preestablished parameters.

As a result of the damage that occurred in November 2005 in the bypass tunnels of the Campos Novos hydropower plant, which caused the postponement of commercial operations for the three generator sets, the requirements to meet certain contractual obligations by the deadline originally foreseen was delayed. ENERCAN's management has already asked the respective financial institutions to review the contractual parameters, and has obtained confirmation that this review will not involve declaration of early maturity of the loan contract.

Certain loans and financing of the direct and indirect subsidiaries are subject to early settlement in the event of changes in the Company’s structure or in the corporate structure of the subsidiaries that result in the loss of the share control or of control over management of the Company by the Company’s current shareholders, or in a reduction in the direct or indirect interest of VBC Energia S.A. in the capital of CPFL Paulista to less than 25%.

Furthermore, failure to comply with the obligations or restrictions mentioned could result in default in relation to other contractual obligations (cross default).

The management believes that, except for the coment related to the indirect subsidiary ENERCAN, the Company and its subsidiaries are in compliance with the restrictive covenants relating to the loans and financing contracts with financial institutions.

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17.DEBENTURES

Composition of Debentures

										2007								2006
		Issued		Remuneration		Amortization Conditions		Collateral		Interest		Current		Non current		Total		Interest		Current		Non current		Total
Parent Company
3rd Issue
Unique series		45,000		CDI + 0.45% p.a.		3 annual installments from September 2012		Unsecured		15,983		-		450,000		465,983		-		-		-		-
CPFL Paulista
2nd Issue
1st series		11,968		109% of the CDI		July 1, 2009.		Unsecured		7,109		-		119,680		126,789		8,756		-		119,680		128,436
2nd series		13,032		IGP-M + 9.8% p.a.		July 1, 2009.		Unsecured		7,368		-		155,217		162,585		6,786		-		144,150		150,936
3rd Issue
1st series		64,000		104.4% of CDI		3 annual installments from December 2011		CPFL Energia guarantee		5,328		-		640,000		645,328		6,247		-		640,000		646,247
										19,805		-		914,897		934,702		21,789		-		903,830		925,619
CPFL Piratininga
1st Issue
Unique series		40,000		104.4% of the CDI		2 annual installments from January 2010		CPFL Energia guarantee		22,641		-		400,000		422,641		27,878		-		400,000		427,878
RGE
2nd Issue
1st series		2,620		IGP-M + 9.6% p.a.		1 installment in April 2011		Unsecured		3,660		-		26,200		29,860		2,692		-		26,200		28,892
2nd series		20,380		106.0% of CDI		1 installment in April 2009		Unsecured		5,584		-		203,800		209,384		6,644		23,000		180,800		210,444
3rd Issue
1st series		1		CDI + 0.60% p.a.		3 annual installments from December 2011		CPFL Energia guarantee		888		-		100,000		100,888		-		-		-		-
										10,132		-		330,000		340,132		9,336		23,000		207,000		239,336
CPFL Geração
								CPFL Energia
								guarantee,
2nd Issue		69,189		TJLP + 4 to 5% p.a.		Semiannual with settlement in June 2009		Receivables and CPFL		1,720		150,416		80,758		232,894		2,923		136,252		230,347		369,522
								Geração common
								nominal shares
Baesa
1st Serie		9,000		105% of the CDI		Quarterly with settlement in August 2016.		Letters of Guarantee		1,008		3,164		25,560		29,732		3,150		-		28,353		31,503
2nd Serie		9,000		IGP-M + 9.55% p.a.		Annually with settlement in August 2016.		Letters of Guarantee		235		1,037		7,257		8,529		1,102		-		9,915		11,017
										1,243		4,201		32,817		38,261		4,252		-		38,268		42,520
										71,524		154,617		2,208,472		2,434,613		66,178		159,252		1,779,445		2,004,875

 

CPFL Energia

On October 25, 2007, 45,000 registered, book-entry and single series subordinated debentures, non-convertible into shares were subscribed and paid up. The par value on the issued date was R$ 10. Interest will be paid every six months, and the first payment is due in March 2008. This issue is part of the Company's fund-raising strategy to finance the acquisition of CPFL Jaguariúna. The total capital of CPFL Jaguariúna was acquired on June 18, 2007 through the subsidiary Perácio, and approved by ANEEL in June 2007. The funds raised through the Debenture Issue was accordingly used to prepay the 4th Issue Promissory Notes of CPFL Energia, which was originally used to pay CPFL Jaguariúna acquisition.

RGE

On December 1, 2007, the subsidiary RGE issued a third series of simple unsecured registered book-entry debentures, without share certificates, not convertible into shares with no scheduled renegotiation option. The debentures will be issued in five series, each comprising a single and indivisible debenture. The objective of the issue was to adjust the financial position of RGE, provide sufficient liquidity to cover the investments in fixed assets and permit the liquidation of debts with maturities to 2009. The total value of the issue willl be R$ 380,000. The first series was subscribed and fully paid in December 2007, in the amount of R$ 100,000, and will have a term of 6 years with final maturity on December 1, 2013. Interest on the debentures is paid half-yearly, on June 1^st and December 1^st of each year.

Maturity of debentures

Maturities of the long-term portion of the debentures as of December 31, 2007 are as follows:

2009		563,657
2010		204,201
2011		477,067
2012		396,666
After 2012		566,881
TOTAL		2,208,472

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Restrictive covenants

The debentures are subject to ceirtan restrictive covenants, including clauses that require maintaining certain financial ratios within predefined parameter ranges. The main ratios are as follows:

CPFL Energia:

• Third issue:

a) Ratio of net debt to EBITDA - less or equal to 3.75; and
b) Ratio of EBITDA to financial income - greater than or equal to 2.25.

CPFL Paulista:

• The second issuance of debentures establishes the following ratios and limits:

a) ratio of EBITDA to financial expenses greater than or equal to 1.5 for all years; and
b) in relation to total capitalization, the level of capital must be at least 40%, while the level of third-party capital must be a maximum of 60%;

• The third issuance of debentures establishes the following ratios and limits:

a) ratio of net indebtedness to EBITDA less than or equal to 3.0; and
b) ratio of EBITDA to financial expenses greater than or equal to 2.25.

RGE:

• The subsidiary RGE must comply with restrictive covenants for its second issue and certain ratios and financial limits of the debentures, as follows:

a) Total debt divided by EBITDA – less or equal to 3.0;
b) EBITDA divided by the financial expenses – greater than or equal to 2.0; and
c) Total debt divided by the total capitalization – less or equal 0.55.

CPFL Piratininga:

• The ratios and financial limits are:

a) ratio of net indebtedness to EBTIDA less than 3.0; and
b) ratio of EBITDA to financial expenses greater than or equal to 2.25.

BAESA:

Stipulates accelerated settlement when the total indebtedness ratio exceeds the limit of 75% of total assets.

Several debentures are subject to early maturity in the event of changes to the corporate structure of the Company or its subsidiaries that involve the loss, on the part of the Company’s current shareholders, of the share control or control of the Company’s management, or a reduction in the direct or indirect participation of VBC Energia S.A. in the capital of the subsidiary CPFL Paulista to less than 25%.

Failure to comply with the restrictions mentioned above could lead to default in relation to other contractual obligations (cross default).

In the opinion of Company’s management, these restrictive conditions and clauses are being adequately complied with.

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18. POST-RETIREMENT BENEFIT OBLIGATION (PENSION PLAN)

The subsidiaries CPFL Paulista, CPFL Geração and CPFL Piratininga, through Fundação CESP, RGE, through Fundação CEEE de Seguridade Social – ELETROCEEE, CPFL Santa Cruz through BB Previdência – Fundo de Pensão Banco do Brasil and CPFL Jaguariúna and subsidiaries through IHPREV Fundo de Pensão, sponsor supplementary retirement and pension plans for their employees. The main characteristics of these plans are as follows:

I – CPFL Paulista

The plan currently in force for the employees of the subsidiary CPFL Paulista is a Mixed Benefit Plan, with the following characteristics:

a) Defined Benefit Plan – in force until October 31, 1997 – a defined benefit plan, which grants a Proportional Supplementary Defined Benefit (BSPS), in the form of a lifetime income convertible into a pension, to participants enrolled prior to October 31, 1997. The amount is established in proportion to the accumulated past service time up to that date, based on compliance with the regulatory requirements for granting. The total responsibility for coverage of actuarial deficits of this plan falls to CPFL Paulista.

b) Mixed model, as from November 1, 1997, which covers:

• retirement for risk (disability and death), under a defined benefit plan, in which the subsidiary assumes responsibility for Plan’s actuarial deficit, and

• scheduled retirement, under a defined contribution plan, up to the granting of a lifetime income, which may or not be convertible into a pension, and does not generate any actuarial liability for the subsidiary CPFL Paulista. The pension plan only becomes a Defined Benefit type plan, consequently generating actuarial responsibility for CPFL Paulista, after the granting of a lifetime income, convertible or not into a pension, based on the balance at the retirement date.

With the modification of the Retirement Plan in October of 1997, a liability was recognized as payable by the subsidiaries in relation to the plan's deficit calculated at the time by the external actuaries of Fundação CESP, to be liquidated in 260 installments, amortized monthly, plus interest of 6% p.a. and monetarily restated by the IGP-DI (FGV). Under the Contractual Amendment, signed with Fundação CESP on July 25, 2006, the payment terms changed to 175 monthly payments and 14 annual installments, as from December 31, 2005, with final maturity on July 31, 2020. The balance of this obligation as of December 31,2007 was R$ 560,190 (R$ 573,715 as of December 31, 2006).

II – CPFL Piratininga

On April 2, 1998, the Supplementary Pensions Department – SPC approved the restructuring of the retirement plan previously maintained by Bandeirante, creating a "Proportional Supplementary Defined Benefit Plan – BSPS”, and a "Mixed Benefit Plan", with the following characteristics:

a) Defined Benefit Plan – in force until March 31, 1998 – a defined-benefit plan, which concedes a Proportional Supplementary Defined Benefit (BSPS), in the form of a lifetime income convertible into a pension to participants registered up to March 31, 1998, to an amount calculated in proportion to the accumulated past service time up to that date, based on compliance with the regulatory requirements for granting. CPFL Piratininga is fully responsible for covering the actuarial deficits of this Plan.

b) Defined Benefit Plan – in force after March 31, 1998 – defined-benefit type plan, which concedes a lifetime income convertible into a pension in relation to the past service time accumulated after March 31, 1998, based on 70% of the average actual monthly salary for the last 36 months of active service. In the event of death while working or the onset of a disability, the benefits incorporate the entire past service time (including the accumulated time up to March 31, 1998). The responsibility for covering the actuarial deficits of this Plan is equally divided between CPFL Piratininga and the participants.

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c) Defined Contribution Plan – implemented together with the Defined Benefit plan effective after March 31, 1998, this is a pension plan up to the granting of lifetime income, convertible (or not) into a pension, and generates no actuarial liability for CPFL Piratininga. The pension plan only becomes Defined Benefit type plan after the concession of the lifetime income, convertible (or not) into a pension, and accordingly starts to generate actuarial liabilities for the subsidiary.

In September 1997, through a contractual instrument of adjustment of reserves to be amortized, Eletropaulo Metropolitana El. São Paulo S.A. (the predecessor of Bandeirante) recognized an obligation to pay referring to the plan deficit determined at the time by the external actuaries of the Fundação CESP, to be liquidated in 260 installments, amortized monthly, plus interest of 6% p.a. and monetarily restated by the IGP-DI (FGV). Under the Contractual Amendment, signed with Fundação CESP on July 25, 2006, the payment terms were amended to 183 monthly payments and 15 annual installments, in relation to the base date of December 31, 2005, with final maturity on March 1, 2021. The balance of the obligation as of December 31, 2007, is R$ 145,813 (R$ 160,258 as of December 31, 2006).

III – RGE

A defined benefit type plan, with a benefit level equal to 100% of the adjusted average of the most recent salaries, including the presumed Social Security benefit, with a Segregated Net Asset administered by ELETROCEEE. Only those employed prior to the spin-off from CEEE to RGE are entitled to this benefit.

IV – CPFL Santa Cruz

Since November 1, 2007, management of the benefits plan of the subsidiary CPFL Santa Cruz, originally performed by FUNSEJEM, has passed to BB Previdência Fundo de Pensão do Banco do Brasil. The subsidiary CPFL Santa Cruz plan is a defined contribution plan.

V – CPFL Geração

The plans currently in force for the employees of subsidiary CPFL Geração are a Proportional Supplementary Defined Benefit (“BSPS”) and a Mixed Benefit Plan, along the same lines as the CPFL Paulista plan.

With the modification of the Retirement Plan, at that point maintained by CPFL Paulista, in October 1997, a liability was recognized as payable by the subsidiary CPFL Geração, relating to the plan deficit calculated by the external actuaries of Fundação CESP, which is being amortized on a monthly basis, in 260 installments, plus interest of 6% p.a. and monetarily restated according to the IGP-DI (FGV). Under the Contractual Amendment, signed with Fundação CESP on July 25, 2006, the payment terms were amended to 178 monthly installments and 14 annual installments, in relation to the base date of December 31, 2005, with final maturity on October 31, 2020. As of December 31, 2007, the balance of the liability, which is monetarily restated annually in line with the evolution of the actuarial deficit calculated in accordance with the criteria of the Supplementary Pensions Department, was R$ 11,318 (R$ 11,575 as of December 31, 2006).

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VI – CPFL Jaguariúna

In December 2005, the companies joined the CMSPREV private pension plan, administered by IHPREV Pension Fund. The plan is structured through the defined contribution type.

The amounts recognized in the balance sheet as of December 31, 2007 and 2006, for the subsidiaries, in accordance with an appraisal prepared by an external actuary, and assumptions confirmed by Management, adjusted to comply with the criteria of CVM Resolution n° 371/00, are presented as follows:

Reconciliation of assets and liabilities		2007		2006
Present value of actuarial liabilities		3,597,623		3,150,340
Fair value of plan assets		(3,164,748)		(2,588,740)
Present value of liabilities exceeding fair value of assets		432,875		561,600
Adjustments due to deferral
Unrecognized actuarial gains		247,904		254,852
Unrecognized cost of past service		(79)		(90)
Net actuarial liability recorded		680,700		816,362
Decrease of 50% on actuarial assets(*)		3,519		-
Net actuarial assets / liabilities recognized on balance sheet		684,219		816,362

The unrecognized actuarial gains as of December 31, 2007 that exceed 10% of the Plan’s liabilities or assets, will be recognized by means of amortization during the remaining useful lives of the plan’s participants.

Changes in net actuarial liabilities were as follows:

		2007		2006
Net actuarial liability at the beginning of the year		816,362		874,259
Assets included due to acquisition of equity interests		-		379
(Income) Expense recorded to statement of income during the year		(46,887)		41,579
Sponsor’s contributions		(85,256)		(99,855)
Net acturial liability at the end of the period		684,219		816,362
Other contributions		36,305		43,999
TOTAL		720,524		860,361
Current		64,484		86,715
Long-term		656,040		773,646
		720,524		860,361

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The external actuary estimates the following net periodic pension cost for 2008, 2007, 2006 and 2005:

		2008		2007		2006		2005
		Project		Realized		Realized		Realized
Cost of service		6,999		6,125		6,234		6,860
Interest on actuarial liabilities		356,370		341,376		343,543		331,513
Expected return on plan assets		(448,405)		(392,038)		(355,699)		(246,145)
Unrecognized cost of past service		11		11		11		11
Unrecognized actuarial gains		(1,239)		(3,859)		(1,870)		-
Increase in liabilities due to adoption of CVM Res. No. 371		-		-		51,483		49,693
Total (income) expense		(86,264)		(48,385)		43,702		141,932
Expected participants’ contributions		(1,570)		(1,942)		(2,123)		(3,007)
Subtotal (income) expense		(87,834)		(50,327)		41,579		138,925
Decrease of 50% on prepaid pension expense (*)		3,683		3,440		-		-
Total		(84,151)		(46,887)		41,579		138,925

(*) As the sponsor, RGE matches the participants’ contributions to this plan. Therefore only 50% was recorded.

The (income) expenses were recorded in the following accounts in the statement of income:

		As of December 31,
		2007		2006		2005
(Income) Expense with the employee pension plans
Operating cost		(46,887)		(7,470)		90,362
Operating expenses (income)		-		(240)		(725)
Extraordinary item net of tax effects		-		32,559		32,559
Taxation of extraordinary item		-		16,730		16,729
Total		(46,887)		41,579		138,925

The extraordinary item recorded in 2006 and 2005 refers to the plan deficit as of December 31, 2001, on adoption of CVM No. 371, which was deferred and amortized in subsequent years, up to December 31, 2006.

The main assumptions that were taken into consideration in the pension calculations at the balance sheet date were as follows:

		CPFL Paulista,
		CPFL Piratininga and
		CPFL Geração				RGE
		2008		2007		2008		2007
Nominal discount rate for
actuarial liabilities		10.24% p.a. (*)		11.30% p.a. (**)		10.24% p.a.		9.39% p.a.
Nominal rate of return on plan assets:						12.32% p.a.		9.39% p.a.
Estimated rate of nominal
salary increases		6.08% p.a.		7.10% p.a.		6.08% p.a.		5.26% p.a.
Estimated long-term inflation rate
(as a basis for establishing the
nominal rates above)		4.0% p.a.		5.0% p.a.		4.0% p.a.		3.2% p.a.
Biometric mortality table		AT-83		GAM83		AT-83		GAM83
Biometric disability table		MERCER TABLE		MERCER TABLE		Light-Average (ix)		Light-Average (ix)
Expected turnover rate:		0.3/(Service time + 1)		0.3/(Service time + 1)		null		0.3/(Service time + 1)

(*) CPFL Paulista and CPFL Geração 14.82% p.a. and CPFL Piratininga 14.14% p.a.
(**) CPFL Paulista and CPFL Geração 15.95% p.a. and CPFL Piratininga 15.80% p.a.

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19.REGULATORY CHARGES

		2007		2006
Fee for the use of water resources		2,327		-
Concession reserve fund — RGR		5,741		3,793
ANEEL inspection fee		1,873		1,759
Fuel consumption account — CCC		27,195		70,802
Energy development account — CDE		31,560		28,659
		68,696		105,013

Concession Reserve Fund – RGR: a reserve fund managed by Eletrobrás, as a Federal Government agency, created to provide funds for payments to concessionaires upon expiration of concession contracts, upon which concessionaires are refunded by the net amount of permanent assets recorded. Decree No. 1771/96 introduced the RGR rate of 2.5% based on property, plant and equipment — in service, limited to 3.0% of total gross operating revenue, net of the state VAT (ICMS).

Fuel Consumption Account – CCC: a contribution made by CPFL Paulista, CPFL Piratininga and RGE to fund the costs of fuel used in the thermoelectric power operating processes within the context of the Brazilian energy system.

Energy Development Account – CDE: created by Law No. 10,438, of April 26, 2002, to promote competition of energy generated through alternative sources such as wind power, small hydroelectric plants, biomass, natural gas, and coal, in the areas served by the Brazilian electric interconnected system and to permit access to electric energy throughout Brazil.

20.RESERVE FOR CONTINGENCIES

		2007								2006
				Escrow								Escrow		Reserve
				Deposits		Reserve for		Other				Deposits		for		Other
		Reserve		related to		Contingencies,		escrow		Reserve		related to		Contingencies,		escrow
		- Gross		Contingencies		net		deposits		- Gross		Contingencies		net		deposits
				(1)				(2)				(1)				(2)
Labor (a)
Various		66,610		51,443		15,167		35,184		70,736		47,597		23,139		13,799
Civil
General damages (b)		14,716		12,670		2,046		20,509		13,535		9,922		3,613		9,023
Tariff increase (c)		15,872		4,068		11,804		5,998		24,207		11,686		12,521		4,769
Energy purchased (d)		40,809		28,168		12,641		-		40,809		28,167		12,642		-
Other		9,792		8,610		1,182		14,308		7,563		6,310		1,253		9,743
		81,189		53,516		27,673		40,815		86,114		56,085		30,029		23,535
Tax
FINSOCIAL (e)		18,171		18,171		-		33,603		17,926		17,926		-		33,149
Increase in PIS and
COFINS		2,592		-		2,592		301		1,053		-		1,053		301
PIS and COFINS -
Interest on
shareholders’ equity (f)		46,811		-		46,811		-		26,045		-		26,045		-
Income tax (g)		52,400		32,323		20,077		375,267		43,993		23,753		20,240		1,532
Other (h)		8,280		3,423		4,857		12,874		3,205		-		3,205		9,530
		128,254		53,917		74,337		422,045		92,222		41,679		50,543		44,512
Total		276,053		158,876		117,177		498,044		249,072		145,361		103,711		81,846

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				Amounts
				included due to
				acquisition of
				equity interests								Monetary
		2006		(note 1)		Addition		Reversal		Payment		Restatement		2007
Labor		70,736		1,788		7,461		(5,227)		(8,148)		-		66,610
Civil		86,114		797		26,149		(16,918)		(15,020)		67		81,189
Tax		92,222		6,150		28,528		(3,015)		(42)		4,411		128,254
Reserve for contingencies - Gross		249,072		8,735		62,138		(25,160)		(23,210)		4,478		276,053
( - ) Escrow deposits (1) + (2)		(227,207)		(6,131)		(478,520)		47,418		26,029		(18,509)		(656,920)

The Company records a provision for legal contingencies for which an adverse outcome is deemed probable based on the opinion of the Company’s management and external legal counsel.

A summary of the main outstanding matters concerning litigation, claims and assessments, for which the Company recorded a provision is, as follows:

a) Labor: The main labor lawsuits relate to claims by former employees or labor unions for payment of salary adjustments (overtime, salary parity, severance pay and other claims). In accordance with the terms of the Bandeirante spin-off, CPFL Piratininga is liable for obligations related to contingent risks of employees located in the respective regions it assumed, whereas obligations arising from corporate lawsuits related to the period prior to the spin-off date, October 1, 2001, are assumed in the proportionate percentage of the owners before the spin-off (56% for Bandeirante and 44% for CPFL Piratininga).

b) General damages: Principally represent claims for indemnities. These matters include claims related to accidents in the Company’s electric grid, damage to consumers and vehicle accidents, among others.

c) Tariff increase: Corresponds to various claims by industrial consumers as a result of increases imposed by DNAEE Administrative Rules 38 and 45, of February 27 and March 4, 1986, respectively, when the “Plano Cruzado” economic plan price freeze was in effect.

d) Energy purchased: As a result of the loss of several free consumers, CPFL Paulista and CPFL Piratininga requested from ANEEL a reduction in the capacity demand determined in their initial supply contracts, which was partially granted by ANEEL. The subsidiaries filed a lawsuit since they do not agree with the reduction in volume of energy determined by ANEEL, alleging a discrepancy in the calculations. Therefore, CPFL Paulista and CPFL Piratininga started to make monthly escrow deposits for the amounts challenged.

e) FINSOCIAL: Refers to a challenge in court against the increase in the rate and payment of FINSOCIAL (tax on revenue) for the period from June 1989 to October 1991.

f) PIS/COFINS — Interest on Shareholders’ equity: At the end of 2005, the Company obtained an injunction with a view to non-payment of PIS and COFINS levied on interest on shareholders’ equity.

g) Income tax: In the subsidiary CPFL Piratininga, the reserve refers to an injunction obtained involving the tax deductibility of CSLL in the IRPJ calculation. In the subsidiary RGE, it basically refers to a request to suspend the decision of the Federal Revenue Service, to allow the deductibility of amounts related to complementary pension benefits of Fundação ELETROCEEE.

h) Other: Refers to other lawsuits in progress at the judicial and administrative levels and of a regulatory nature arising from the ordinary course of business involving mainly tax matters relating to INSS (Social Security), FGTS (Severance Pay Fund) and SAT (Occupational Accident Insurance).

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Possible losses: The Company is also a party to lawsuits for which an adverse outcome is deemed possible. In connection with these lawsuits, the Company’s management, based on the advice of external counsel, believes that the Company has a solid defense. However, there is not a consistent trend in decisions issued by Brazilian courts or any decisions from the Brazilian superior courts that would enable the Company to classify losses regarding the related claims as either probable or remote. Claims relating to possible losses as of December 31, 2007 are as follows: (i) claims relating to several labor issues amounting to approximately R$ 211,432 (R$ 168,847 as of December 31, 2006); (ii) claims relating to civil litigation, principally related to general damages, environmental and tariff increase which amount to approximately R$ 398,739 (R$ 421,474 as of December 31, 2006); and (iii) claims relating to tax litigation, principally related to income tax and tax on revenue (ICMS, FINSOCIAL, PIS e COFINS), amounting to approximately R$ 466,769 (R$ 327,475 as of December 31, 2006).

Other - Escrow Deposits - Income Tax: refers to discussion of the deductibility for income tax purposes of expense recorded in 1997 in respect of the welfare deficit of the pension plan of employees of the subsidiary CPFL Paulista in relation to Fundação CESP, due to the renegotiation and renewal of debt in that year. After consulting the Brazilian Federal Income Office, the subsidiary CPFL Paulista obtained a favorable answer in Note MF/SRF/COSIT/GAB n° 157 of April 9, 1998, and used the tax deductibility of the expense, thereby generating tax loss carryforwards in that year. In March 2000, CPFL Paulista was assessed by the tax inspectors in relation to use of the tax loss carryforwards in 1997 and 1998. In 2007, as a result of the legal decision demanding the deposit to permit continuity of the discussions, the Company made an escrow deposit of R$ 360,255 (R$ 373,116 monetarily restated to December 31, 2007). Based on the updated position of the legal counsel in charge of this case, the risk of loss continues to be classified as remote.

Management of the Company and its subsidiaries, based on the opinion of the legal counsel, considers that there are no significant risks that are not covered by reserves recorded in the financial statements or that could result in a significant impact on future results.

21.OTHER

		Current				Long Term
		2007		2006		2007		2006
Consumers and concessionaires (a)		55,724		50,927		-		-
Regulatory liability (note 3)		150,360		49,816		137		732
Energy Efficiency Programs (PEE) (b)		45,241		40,102		59,853		44,387
Research and Development (R&D) (b)		34,280		25,435		44,535		38,049
National Scientific and Technological Development
Fund (FNDCT) (b)		24,220		25,610		3,257		5,868
Energy Research Company (EPE) (b)		12,264		34,626		1,113		-
Fund for reversal		-		-		17,751		17,750
Advances (c)		11,475		7,780		82,597		-
Interest on compulsory loan (d)		3,954		3,998		-		-
Emergency Capacity Charge and Emergency Energy
Purchase Charge (ECE/EAEE) (e)		4,466		10,386		-		-
Provision for environmental expenses		778		-		3,684		13,321
Payroll		9,617		3,951		-		-
Profit sharing (note 28)		23,893		20,832		-		-
Other		51,451		30,230		6,565		7,834
Total		427,723		303,693		219,492		127,941

a) Consumers and concessionaires: Refer to liabilities in connection with bills paid twice and/or adjustments to billing to be compensated or refunded to consumers, or related to customers enrolled in the “Universal Service Program.” Liabilities to concessionaires refer to various transactions relating to the partial spin-off of Bandeirante by the subsidiary CPFL Piratininga.

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b) Research and development and energy efficiency programs – The subsidiaries recognized liabilities related to amounts already billed in tariffs (1% of Net Operating Income), but not yet invested in the Research and development and energy efficiency programs. These amounts are monthly updated by the SELIC rates, through the time of realization.

c) Advances: Refer to advances made by consumers to carry out works and services. Non-current refers to the contribution made exclusively by the shareholder Chapecoense to Foz do Chapecó. The subsidiary CPFL Geração will contribute funds relating to its participation in proportion to the requirements of the Foz do Chapecó Project.

d) Interest on compulsory loans: Refers to the passing on of funds from Eletrobrás to industrial consumers.

e) Emergency Capacity Charge (“ECE”) and Emergency Energy Purchase Charge (“EAEE”) – Refer to the tariff charges relating to the contracting of emergency capacity and energy collected from consumers through January 2006 and passed through to the Brazilian Emergency Power Trader (“CBEE”).

22.SHAREHOLDERS’ EQUITY

The Company is a listed corporation with shares traded on the São Paulo and New York Stock Exchanges. The shares are negotiated abroad in the form of American Depositary Receipts – ADRs, which individually are represented by 3 commom shares.

According to its Bylaw, the Company is authorized to increase its capital, when approved by the Board of Directors, of an additional 500,000,000 commom shares. The Shareholders’ equity is represented by 479,910,938 outstanding common shares, without par value, distributed as follows:

		2007				2006
Shareholders		Shares		%		Shares		%
VBC Energia S.A.		136,329,808		28.41		139,002,673		28.97
521 Participações S.A.		149,233,727		31.10		149,230,373		31.11
Bonaire Participações S.A.		60,713,511		12.65		60,713,511		12.65
Other Shareholders		133,599,816		27.83		130,778,505		27.26
Board Members		3,112		0.00		11		0.00
Statutory Directors		30,964		0.01		31,657		0.01
Total		479,910,938		100.00		479,756,730		100.00

The Extraordinary General Meeting of the Company and the subsidiary RGE, held on December 18, 2007, approved the merger of all the common shares of RGE’s minority shareholders in the equity of CPFL Energia by an increase of R$ 6,385 in the Company’s capital, through the issue of 154,208 common shares.

In July 2007, the Company's Board of Directors approved the declaration and payment of interim dividends totaling R$ 842,375, corresponding to R$ 1.755837558 per share, on the results for the first half-year of 2007.

During 2007, the Parent Company made a total payment of R$ 1,557,428 regarding the dividends declared on December 31, 2006 and June 30, 2007.

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22.1 - Allocation of Net Income for the Year

The Company’s By-laws stipulate the distribution of a minimum dividend of 25% of net income, adjusted in accordance with the law, to the holders of its shares.

For this year, the Company’s management is proposing distribution of the remaining balance of net income, through the declaration of R$718,889 in the form of dividends, corresponding to R$1.497964530 per share, as shown below:

Net Income — Company		1,643,436
Statutory reserve — Recognition		(82,172)
Adjusted Net income		1,561,264
Interim dividend		(842,375)
Proposed dividend		(718,889)
Retained earnings		-

22.2 – Capital Reserve

Refers to gain on selling of treasury shares derived from the exercise by shareholders of the right to withdraw, at the time of the merger of the shares of non-controlling shareholders. The shares were sold resulting in a gain of R$ 16, recorded as a Capital Reserve.

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23.OPERATING REVENUES

		No. of Consumers
		(in thousands) (*)						Gwh(*)						R$
Revenue from Electric Energy Operations		2007		2006		2005		2007		2006		2005		2007		2006		2005
Consumer class
Residential		5,368		4,937		4,805		10,766		9,489		8,783		4,555,313		3,922,483		3,556,914
Industrial		87		81		81		16,692		16,882		16,995		4,123,411		3,662,592		3,328,655
Commercial		484		448		446		6,509		5,779		5,329		2,494,199		2,145,111		1,868,848
Rural		265		237		234		2,511		1,966		1,730		482,039		369,114		312,614
Public administration		41		37		36		972		862		800		352,223		303,339		261,696
Public lighting		5		3		2		1,284		1,152		1,098		276,622		241,337		225,472
Public services		6		5		5		1,590		1,472		1,400		448,637		390,015		329,866
Billed		6,256		5,748		5,609		40,324		37,602		36,135		12,732,444		11,033,991		9,884,065
Own consumption		1		1		1		30		25		25		-		-		-
Unbilled (Net)		-		-		-		-		-		-		(32,826)		75,361		39,607
Emergency charges—ECE/EAEE		-		-		-		-		-		-		48		3,052		229,153
Realization of extraordinary tariff adjustment (note 3 a)		-		-		-		-		-		-		(223,510)		(257,983)		(258,143)
Realization of free energy (note 3 a)		-		-		-		-		-		-		(76,487)		(103,406)		(96,752)
Tariff review – Remuneration basis (note 3 b.1)		-		-		-		-		-		-		8,301		26,970		(80,686)
Realization of tariff review - Remuneration basis (note 3 b.1)		-		-		-		-		-		-		(41,834)		98,010		48,762
Tariff review – Depreciation (note 3 b.1)		-		-		-		-		-		-		6,310		10,402		28,442
Realization of tariff adjustment – Depreciation (note 3.b.1)		-		-		-		-		-		-		(36,324)		-		-
Tariff adjustment – Purchase of electric energy from ltaipu (note 3 b.3)		-		-		-		-		-		-		-		15,152		33,339
Realization of tariff adjustment – Purchase of electric energy from ltaipu (note 3 b.3)		-		-		-		-		-		-		(13,052)		(35,615)		-
Tariff adjustment - other (note 3 b.3)		-		-		-		-		-		-		26,768		25,642		2,088
Realization of tariff adjustment - other (note 3 b.3)		-		-		-		-		-		-		(39,212)		(3,122)		(328)
PIS and COFINS – Generators pass through (note 3)		-		-		-		-		-		-		(7,579)		(39,367)		22,958
Realization PIS and COFINS – Generators pass through (note 3 b.3)		-		-		-		-		-		-		13,370		14,089		(11,424)
Discount of tariff adjustment TUSD and
irrigation (note 3 b.3)		-		-		-		-		-		-		77,489		46,792		4,009
Realization of discount of tariff adjustment
TUSD discount and irrigation (note 3 b.3)		-		-		-		-		-		-		(38,690)		(10,688)		(3,956)
ELECTRICITY SALES TO FINAL CONSUMERS		6,257		5,749		5,610		40,354		37,627		36,160		12,355,216		10,899,280		9,841,134
Furnas Centrais Elétricas S.A								3,026		3,026		3,025		298,818		273,480		298,676
Other concessionaires and licensees								3,842		3,484		2,197		284,983		200,376		123,160
Current electric energy								1,863		951		938		99,141		26,673		38,293
ELECTRICITY SALES TO WHOLESALERS								8,731		7,461		6,160		682,942		500,529		460,129
Revenue due to network usage charge – TUSD														799,634		691,896		472,607
Low income consumers’ subsidy (note 3 d)														13,934		23,835		21,329
Other revenues														355,658		111,512		111,859
OTHER OPERATING REVENUES														1,169,226		827,243		605,795
Total														14,207,384		12,227,052		10,907,058

^(*) Unaudited

See Note 3 (a) (Free energy) and Note 11.c (Receivables from BAESA’s shaheholders) in respect of accounting records involving other revenue and income.

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24.ELECTRICITY COST

		GWh (*)						R$
		2007		2006		2005		2007		2006		2005
Electricity purchased for resale
Electricity purchased in the regulated market (ACR)
Itaipu Binacional		10,990		10,761		10,501		982,990		886,087		883,901
Furnas Centrais Elétricas S.A		1,207		892		2,918		88,598		63,161		248,236
CESP — Cia. Energética de São Paulo		1,071		372		2,556		83,999		26,291		217,194
Cia. de Geração de Energia Elétrica do Tietê		377		387		1,218		32,631		32,800		102,833
Duke Energy Inter. Geração. Paranapanema S.A		1,195		939		1,506		116,076		88,614		137,761
Tractebel Energia S.A		8,110		6,690		3,789		1,006,452		801,003		425,580
Petrobrás – Petróleo Brasileiro S.A		1,717		1,717		1,769		195,924		198,584		173,058
EMAE — Empresa Metropolitana de Águas e Energia		28		20		188		1,951		1,351		15,622
Cia. Estadual Energia Elétrica (CEEE)		96		69		186		7,260		4,304		12,395
AES Uruguaiana Ltda		1,244		1,119		834		163,188		123,883		96,881
CCEE		783		520		507		108,429		18,660		7,326
Other		2,856		1,739		985		305,757		168,367		78,811
		29,674		25,225		26,957		3,093,255		2,413,105		2,399,598
Energy purchased in the free market (ACL)		18,488		20,773		16,292		1,313,965		1,375,919		1,060,874
		48,162		45,998		43,249		4,407,220		3,789,024		3,460,472
Deferral related to variations of CVA, net								96,014		4,105		57,691
Surplus and shortages of energy (note 3 b.3)								(74,041)		8,643		(44,212)
Tarriff Review – Reimbursement to the consumer (note 3 b.3).								26,213		-		-
PIS and COFINS — Generators pass-through (note 3 b.3)								-		(39,256)		22,958
PIS/COFINS credit								(403,666)		(343,319)		(322,144)
Other								540		-		-
Subtotal								4,052,280		3,419,197		3,174,765
Electricity network usage charges
Basic network charges								631,665		563,910		538,359
Charges for transmission from Itaipu								66,602		62,013		59,633
Connection charges								63,380		35,594		46,874
System Service Charges (ESS)								5,016		21,039		24,291
								766,663		682,556		669,157
Deferral related to variations of CVA, net								1,738		167,628		163,189
PIS/COFINS credit								(65,620)		(76,107)		(75,160)
Subtotal								702,781		774,077		757,186
Total								4,755,061		4,193,274		3,931,951

^(*) Unaudited

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25.OPERATING EXPENSES

		2007		2006		2005
Sales and Marketing
Personnel		55,388		47,897		37,190
Materials		2,444		9,931		5,955
Outside services		59,669		31,721		31,354
Allowance for doubtful accounts		47,534		83,324		63,893
Depreciation and amortization		9,977		7,078		5,997
Collection fee		47,570		50,090		43,453
Other		205,471		14,190		9,668
Subtotal		428,053		244,231		197,510
General and Administrative Expenses
Personnel		115,537		102,639		76,552
Materials		5,548		5,258		4,769
Outside services		149,450		130,126		112,842
Leases and rentals		4,397		3,852		5,716
Depreciation and amortization		20,386		18,311		23,098
Publicity and advertising		11,644		8,657		7,677
Legal, court and indemnities		24,574		29,229		17,183
Donations, contributions and subsidies		7,324		4,005		6,646
Other		15,044		12,332		12,444
Subtotal		353,904		314,409		266,927
Other Operating Expenses
Inspection fee		21,258		17,942		16,637
Losses on extraordinary tariff adjustment and free energy (note 3 a)		9,735		1,038		91,806
Other		3,430		407		2
Subtotal		34,423		19,387		108,445
Amortization of goodwill		176,306		151,844		125,709
Total		992,686		729,871		698,591

See Note 3a for the amounts recorded in other sales and marketing expenses in relation to the writing off of free energy accounts receivable.

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26. FINANCIAL INCOME (EXPENSE)

		2007		2006		2005
Financial income
Yield on temporary cash investments		106,635		132,397		124,761
Late payment charges		111,057		92,003		86,451
Interest on prepaid income and social contribution taxes		18,823		17,116		9,381
Monetary variations		112,093		-		27,906
Interest — CVA and Parcel “A”		68,300		106,817		144,449
Discount on purchase of ICMS credit		14,557		13,503		11,527
Interest — Extraordinary tariff adjustment (note 3 a)		20,542		51,488		160,346
Dividends received from noncontrolling investments		87		4,667		9,230
Increase in PIS and COFINS		-		122,140		-
PIS and COFINS - Interest on shareholder’s equity (note 20)		(17,761)		(14,760)		(17,910)
Other		59,092		72,523		48,200
Subtotal		493,425		597,894		604,341
Financial expense
Debt charges		(526,423)		(535,072)		(585,962)
Banking expenses		(81,175)		(65,507)		(56,916)
Monetary variations		-		(2,127)		-
Derivatives		(222,507)		(99,569)		(135,175)
Other		(33,921)		(46,082)		(37,987)
Subtotal		(864,026)		(748,357)		(816,040)
Net financial expense		(370,601)		(150,463)		(211,699)

Monetary variations include gain or losses relating to inflation adjustments of assets and liabilities as required contractually or legally, or foreign exchange gain or losses relating to assets and liabilities denominated in foreign currency.

The income of R$ 122,140 recorded in 2006 refers to reversal of the contingent liability and recording of tax credits related to PIS and COFINS, due to the final favorable outcome on the appeal filed by the subsidiaries, challenging the legality of the increase in the calculation base for these contributions.

27.NONOPERATING INCOME (EXPENSE)

		2007		2006		2005
Nonoperating income
Gain on disposal of property, plant and equipment		2,310		2,283		9,533
Gain on sale of equity interest in subsidiaries		3,309		69,112		-
Inventory adjustment		196		-		-
Other		572		2,482		975
Subtotal		6,387		73,877		10,508
Nonoperating expenses
Loss on changes in equity interest in subsidiaries		-		(4)		(1,012)
Loss on deactivation of property, plant and equipment		(23,749)		(15,932)		(3,180)
Loss on disposal of property, plant and equipment		(5,650)		(2,974)		(6,176)
Losses due to non-utilization of studies and designs		(5,914)		(754)		(15)
Other		(1,721)		(4,376)		(485)
Subtotal		(37,034)		(24,040)		(10,868)
Total		(30,647)		49,837		(360)

The gain on sale of equity interest is related to the sale of equity interest held for investments.

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28.PROFIT SHARING

In accordance with the Collective Bargaining Agreement, the Company and its subsidiaries implemented a profit sharing program, based on agreed operating and financial targets previously established with the employees. The amount of this profit sharing for 2007 was R$28,699 (R$ 33,392 in 2006 and R$ 20,252 in 2005). After the prepayment in the year 2007, the remaining balance accrued is R$ 23,893 (note 21).

29.RELATED PARTIES

Transactions with related parties are summarized below:

		For the Years Ended December 31,
		2007		2006		2005
Fixed Asset Purchases
Construções e Comércio Camargo Corrêa S.A		63,183		115,379		131,142
Camargo Corrêa Equipamentos e Sistemas S.A		5,511		1,772		2,667
Cimento Rio Branco S.A. — Votorantim Cimentos		14,467		9,209		6,945
Siderúrgica Barra Mansa S.A. — Votorantim Metais		5,691		6,323		304
Companhia Brasileira de Alumínio		3,955		1,649		1,185
Operating Expenses
Companhia Brasileira de Aluminio		7,161		4,289		2,846
Operating Revenues
Votorantim Celulose e Papel S.A		16,758		71,176		36,483
Industrias Votorantim S.A		19,481		65,350		31,057
Votocel Filmes Flexiveis Ltda		6,782		7,162		12,040
Cimento Rio Branco S.A. — Votorantim Cimentos		13,492		71,260		22,103
Camargo Correa Cimentos S.A		7,770		7,733		700
Companhia Brasileira de Alumínio		43,112		11,930		1,129
Votorantim Metais		19,264		-		-
Votorantim Comercial de Energia Ltda		24,865		-		-
Financial Income
Banco Votorantim S.A		6,948		902		-
Financial Expenses
Banco Votorantim S.A		1,823		547		1,940

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The balances with related parties are summarized below:

		As of December 31,
		2007		2006
Financial investments
Banco Votorantim S.A		46,412		32,212
Accounts receivables
Camargo Corrêa Cimentos S.A		963		1,233
Companhia Brasileira de Alumínio		45		2,139
Cimento Rio Branco S.A. — Votorantim Cimentos		5		-
Siderúrgica Barra Mansa S.A. — Votorantim Metais		71		-
Construções e Comércio Camargo Correa S.A		1,300		-
Votorantim Comercial de Energia Ltda		6,100		-
Suppliers
Construções e Comércio Camargo Corrêa		3,901		14,883
Cimento Rio Branco S.A. — Votorantim Cimentos		655		993
Companhia Brasileira de Alumínio		9,323		7,906
Siderúrgica Barra Mansa S.A. — Votorantim Metais		8,468		7,051
Camargo Correa Equipamentos e Sistemas		-		155

The nature of those transactions are described below:

Fixed assets purchases: refers mainly to the acquisition of material and equipment for the use in the distribution network and for the Power Plant under constructions as described in note 1;

Operating expenses: purchase of material for use and consumption;

Operating revenues: Income from electric energy sales;

Financial income: yield from investments, remunerated based on the variation of the CDI and with daily liquidity;

Financial expenses: interest incurred on loans and financing.

30. INSURANCE

The subsidiaries maintain insurance policies with coverage determined based on advice by specialists, taking into account the nature and degree of risk, for amounts considered sufficient to cover any significant losses on assets and/or liabilities.

The main insurance policies cover the following:

DESCRIPTION		TYPE OF COVERAGE		2007		2006
Property, plant and equipment		Fire, lightning, explosion, machinery
		breakdown and electrical damage		1,936,162		1,361,841
Transportation		Domestic transportation		43,700		43,000
Stored materials		Fire, lightning, explosion and robbery		36,700		12,000
Automobiles		Comprehensive coverage		81,488		3,001
Civil liability		Electricity distributors		32,998		30,000
Personnel		Group life and personal accidents		106,747		114,078
Other		Other		35,268		42,530
TOTAL (*)				2,273,063		1,606,450

(*) Unaudited

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31.FINANCIAL INSTRUMENTS

31.1 CONSIDERATIONS ON RISKS

The business of the Company and its subsidiaries comprises mainly generation, sale and distribution of electric energy, as public service utilities, whose activities and tariffs are regulated by ANEEL. The main market risk factors that affect business are the following:

Exchange Rate Risk

This risk arises from the possibility that the Company may incur losses and cash constraints on accounts due to exchange rate fluctuations, which would increase the balances of liabilities in foreign currency. In order to protect against that risk, the Company has contracted hedge/swap operations so that their liabilities are indexed to domestic index variations (CDI – see note 16). The Company’s subsidiaries are also exposed in their operations to exchange variations in the purchase of electric energy from Itaipu. The compensation mechanism - CVA protects the companies against possible losses, as mentioned in Note 3. These operations are recorded on the accrual basis and in accordance with the conditions of the contractual financial instrument.

Interest Rate Risk

This risk arises from the possibility that the Company may incur losses due to interest rate fluctuations, which would increase the financial expenses related to loans, financing and debentures. For some loans borrowed in local currency, the Company has, as counterparts, regulatory assets updated according to the variation of the SELIC rate. The subsidiaries have also increased the share of loans linked to the variation in the TJLP, an index less susceptible to the oscillations of the financial market.

Credit risk

The risk arises from the possibility that subsidiaries may incur losses due to the difficulty in receiving amounts billed to their customers. This risk is considered low by the subsidiaries in view of the dispersal in the number of customers and the policy of collection and supply cuts for delinquent customers.

Energy Shortage Risk

The energy distributed by the Company is primarily generated by hydroelectric plants. A long period of rain shortage and an increase in demand over the projected amounts may reduce the volume of water in reservoirs of power plants resulting in losses due to the increase in costs for purchasing energy or reduction of revenues if a new rationing program becomes necessary, similar to that of 2001. Given the current level of the reservoirs, the National Electric System Operator (“ONS”) does not expect that a new rationing program will be necessary in 2008.

Risk of Acceleration of Debts

The Company has loans and financing, as well as debentures, which include covenants requiring the Company to comply with certain ratios and conditions. Those restrictive clauses are properly monitored by management and do not limit the capacity to operate normally.

31.2 FAIR VALUES OF FINANCIAL INSTRUMENTS

The Company and its subsidiaries maintain operating and financial policies and strategies aimed at ensuring the liquidity, security and profitability of their assets. As a result, control and follow-up procedures are in place on the transactions and balances of financial instruments, for the purpose of monitoring the risks and current rates in relation to those practiced in the market.

The main financial asset and liability instruments as of December 31, 2007 are described below, together with the criteria for their valuation and recording in the financial statements:

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Cash, cash equivalents and Financial Investments

Comprise cash, banks, temporary cash investments and debt securities. The fair value of these assets approximates the amounts stated in the balance sheets (note 4 and 5).

Regulatory Assets and Liabilities

Basically composed of the Extraordinary Tariff Recovery, Free Energy, Parcel “A”, Assets and Liabilities related to the Tariff Review and Tariff Adjustment, low income subsidy and others. These assets and liabilities are derived from the effects of the 2001 rationing plan, amounts related to the deferral of tariff costs and gains, and changes in tax and regulatory legislation. These amounts are valued according to the criteria defined by ANEEL, with the characteristics described in Note 3.

Loans and financing

Recorded in compliance with the criteria contractually established, with the characteristics defined in Note 16. As described above, on December 31, 2007, the Company and its subsidiaries maintained financial swap instruments for their foreign currency denominated loans and interest charges. The purpose of these contracted instruments is to protect the operations of the subsidiaries against exchange and interest rate fluctuations, and are not used for speculative purposes.

Debentures

The debentures issued by the subsidiaries are traded on the market and are recorded according to the criteria stipulated at the time of issuance, according to the characteristics defined in Note 17.

Investments in subsidiaries

The Company has investments recorded according to the equity method in companies whose stock is traded on the capital market. The Company’s management considers that the trading volume and value of these shares is not representative of the fair value of the respective companies considering the small volume of stock transactions on the market.

Following are the book and fair values of the Company’s financial instruments as of December 31, 2007 and 2006.

		2007				2006
		Book Value		Fair Value		Book Value		Fair Value
Loans and financing		3,813,001		3,695,602		3,163,523		3,198,518
Debentures		2,434,613		2,466,855		2,004,875		2,086,807
Derivatives		175,744		188,560		74,758		77,137
Total		6,423,358		6,351,017		5,243,156		5,362,462

The estimated fair value of the Company’s financial instruments was prepared based on models that discount future cash flows to present value, comparison with similar transactions contracted on dates close to the closing date of the financial statements, and comparisons with average market parameters. In the case of operations with no similar transactions in the market, principally related with the energy rationing program, regulatory assets and liabilities and receivables from CESP, the Company assumed that the fair value corresponds to the book value.

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DERIVATIVES

As of December 31, 2007 and 2006 the Company has swap contracts in connection with exchange losses resulting from the devaluation of the Brazilian real compared to the US dollar and Japanese yens or interest rates in the notional amount, as summarized as follows:

								Aggregate		Unrealized
								notional		Gains (Losses)
Type		Date of contracts		Expiration dates		Currency.		amount .		R$
December 31, 2007
Swap (US$/CDI)		July 2007 and December 2007		January 2008 to February 2008		US$		28,688		(3,711)
Swap (JPY/CDI)		September 2006 to September 2007		February 2008 to April 2010		JPY		56,787,521		(173,046)
Swap (104.4% CDI / CDI + 0.45%)		February 2006 to September 2007		March 2008 to September 2009		R$		515,000		1,013
Total Losses										(175,744)
December 31, 2006
Swap (US$/CDI)		July 2004 to November 2006		January 2007 to July 2007		US$		36,925		(45,691)
Swap (JPY/CDI)		June 2006 to December 2006		June 2007 to September 2009		JPY		28,384,982		(29,067)
Total Losses										(74,758)

32.COMMITMENTS

The Company’s commitments under long-term energy purchase contracts and power plant construction projects are as follows:

		Duration		2008		2009		2010		2011		2012		Thereafter		Total
Energy purchase contracts (except Itaipu)		2 to 20 years		4,239,957		4,357,785		4,458,481		4,600,493		4,811,469		50,634,834		73,103,019
Itaipu		20 years		911,684		913,412		1,009,803		1,006,150		1,029,973		15,665,107		20,536,129
Power plant construction projects (a)		2 to 31 years		362,810		276,167		144,700		40,340		29,149		641,041		1,494,207

(a) Power plant construction projects include commitments made by the Company corresponding to its proportional share, public utilities liabilities (note 12), and bank guarantees relating to the jointly-controlled under development companies described in Note 1.

33.RELEVANT FACTS

Legislation Changes – Amendments to Law 6.404/76 – Law 11.638/07

Law 11.638/07 was enacted on December 28, 2007, amending, revoking and introducing additional provisions in Brazilian Corporate Law (Law 6.404/76) relating to disclosure and preparation of Financial Statements. These changes came into effect as from January 1, 2008 and are summarized below:

a) Pre-fixed financial assets and liabilities should be adjusted to present value, if the effects are relevant;
b) Certain financial instruments and derivatives should be recorded at a fair value;
c) Recording of assets and liabilities should be recorded at market value in the case of mergers, amalgamations or spin-offs between unrelated parties.
d) Substitution of Statement of Changes in Financial Position - DOAR by the Statement of Cash Flows and mandatory disclosure of the Statement of Value-added;
e) Inclusion of new subgroups of accounts as Intangible in assets and the Adjustment of Equity Valuation Account in Shareholders’ Equity;

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The Law also requires the rules issued by CVM to be in line with international accounting standards, based on the International Accounting Standards Board (“IASB”) rules.

The Company has already adopted some of the policies established by the new Law, such as disclosure of the Statements of Cash Flow and is analyzing the impact of the other changes required by the law, which are to be applied in full during 2008, pursuant to the rules published by the regulatory authorities.

34.SUBSEQUENT EVENTS

- ANEEL preliminarly established the tariff adjustment and financial components included in the tariff review on January 29, 2008 for the subsidiaries CPFL Santa Cruz, CPFL Jaguari, CPFL Mococa, CPFL Leste Paulista and CPFL Sul Paulista, on April 7, 2008, for CPFL Paulista and on April 17, 2008 for RGE, in accordance with the table below:

		CPFL						CPFL		CPFL
		Santa		CPFL		CPFL		Leste		Sul		CPFL
		Cruz		Jaguari		Mococa		Paulista		Paulista		Paulista		RGE
Verified revenue		213,312		87,989		54,148		77,145		92,390		5,175,546		1,950,452
Parcel “A”		124,331		68,585		30,989		42,854		58,690		3,314,145		1,324,735
Gross remuneration base		14,894		4,880		3,658		11,696		7,745		351,310		179,713
Depreciation		10,594		2,492		1,816		4,322		4,230		252,111		97,139
Reference company		42,555		11,794		13,419		16,581		19,602		542,368		241,662
Delinquency		1,463		220		126		187		225		34,603		14,548
Parcel “B”		69,506		19,386		19,019		32,786		31,802		1,180,392		533,062
Required revenue (Parc. A+B)		193,837		87,971		50,008		75,640		90,492		4,494,537		1,857,797
(-) Other revenues		(1,291)		(291)		(411)		(569)		(860)		(27,276)		(12,170)
Net required revenue		192,546		87,680		49,597		75,071		89,632		4,467,261		1,845,627
Financial components		5,013		(1,079)		1,366		777		(524)		3,336		187,320
Financial repositioning		-9.73%		-0.35%		-8.40%		-2.69%		-2.98%		-13.69%		-5.37%
Financial components		2.60%		-1.23%		2.75%		1.04%		-0.58%		0.08%		10.15%
Total repositioning		-7.13%		-1.58%		-5.65%		-1.65%		-3.57%		-13.61%		4.77%
Factor “Xe”		0.22%		2.10%		0.24%		1.07%		1.31%		0.83%		0.66%
Consumers’ repositioning (*)		-8.14%		-3.56%		-8.15%		-1.45%		-7.11%		-17.21%		2.52%

(*) Represents the average effect for consumers, as a result of the elimination from the tariff base of financial components added in the 2007 annual adjustment.

In April 2008, in the context of the periodic tariff revision of CPFL Paulista, ANEEL determined that the subsidiary CPFL Paulista would not be allowed to recover some 2007 energy costs that it had capitalized in the “Energy surpluses and shortages” regulatory account, on the grounds that the costs should have been avoided by different purchasing practices under a supply contract between CPFL Paulista and the subsidiary CPFL Brasil. These practices will be analyzed by the Company and ANEEL. Therefore, CPFL Paulista’s 2008 periodic tariff revision is still preliminary and subject to challenge.

CPFL Piratininga, which also has a supply contract with CPFL Brasil, also capitalized 2007 costs under similar circumstances. At December 31, 2007 the total regulatory assets arising from these costs at CPFL Paulista and CPFL Piratininga was R$ 109,331.

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In the first quarter of 2008, following ANEEL’s determination, those regulatory assets and the additional amount recorded in the period were fully impaired and an additional provision to reimburse consumers was recognized, resulting in a total charge in the consolidated statements of income of R$ 111,895, net of taxes.

- The Castro Alves power plant began commercial operations in March 2008 and is currently operating at partial capacity with the entrance of the first and second generator. The third generator is scheduled to begin operations at the second quarter of 2008. When completed, Castro Alves will have an installed capacity of 130 MW and assured energy of 560.6 GWh / year. The entire CERAN Complex will be fully operational by the end of 2008.

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35. SUMMARY OF DIFFERENCES BETWEEN ACCOUNTING PRINCIPLES GENERALLY ADOPTED IN BRAZIL (“BRAZILIAN ACCOUNTING PRINCIPLES”) AND ACCOUNTING PRINCIPLES GENERALLY ACCEPTED IN THE UNITED STATES OF AMERICA (“U.S. GAAP”)

The accompanying consolidated financial statements are prepared in accordance with Brazilian Accounting Principles, which differs in certain significant respects from U.S. GAAP. Following is a reconciliation of net income and shareholders’ equity of the differences between Brazilian Accounting Principles and U.S. GAAP as of December 31, 2007 and 2006 and for each of the three years in the period ended December 31, 2007.

I — Reconciliation of the differences between U.S. GAAP and Brazilian Accounting Principles

		2007		2006		2005
Net income under Brazilian Accounting Principles		1,643,436		1,404,096		1,021,278
Capitalization of interest costs:
Reversal of capitalized interest under Brazilian Accounting Principles		(3,305)		-		-
Interest capitalized under U.S. GAAP		32,577		25,986		12,435
Reversal of depreciation of capitalized interest under Brazilian Accounting Principles		627		552		3,342
Depreciation of capitalized interest under U.S. GAAP		(7,917)		(4,829)		(7,662)
Effect of disposals on capitalized interest		(279)		10		(581)
Capitalization of administrative costs:
Reversal of administrative expenses capitalized under Brazilian Accounting Principles		(48,247)		(41,523)		(13,822)
Reversal of depreciation of capitalized administrative costs under Brazilian Accounting Principles		6,873		2,839		1,328
Effect of disposals on capitalized administrative costs		141		130		73
Monetary restatement 1996 and 1997:
Depreciation of monetary restatement under U.S. GAAP		(224)		(217)		(1,709)
Effect of disposals on monetary restatement		(14)		(17)		(70)
Special obligations:
Effect of depreciation under U.S. GAAP		-		(33,596)		16,381
Accounting for the effects of regulation:
Recognition of electricity sales to final consumers (RTE) that were previously recorded under
Brazilian Accounting Principles, net of tax on revenues		-		-		82,695
Reversal of interest on RTE recorded under Brazilian Accounting Principles		-		-		(6,876)
Recognition of interest on RTE that was previously recorded under
Brazilian Accounting Principles		-		-		67,395
Reversal (Provision) for expenditure on research and development and energy efficiency
programs		48,517		10,071		(21,093)
Business combinations and goodwill:
Basis differences:
Depreciation of basis difference in property, plant and equipment		539		(47,738)		(20,598)
Effect of disposals of property, plant and equipment		(13,081)		(14,550)		(8,724)
Reversal of goodwill amortization under Brazilian Accounting Principles		176,306		147,645		117,561
Amortization of intangible concession assets under U.S. GAAP		(209,761)		(261,445)		(185,040)
Amortization of lease agreement intangible under U.S. GAAP		(18,616)		(18,616)		(18,616)
Reversal of deferred tax expense related to the amortization of merged goodwill recorded
under Brazilian Accounting Principles		46,025		38,452		37,981
Accounting for the leasing transactions:
Reversal of revenues recorded under Brazilian Accounting Principles, net of taxes on revenues		(298,903)		(273,480)		(298,676)
Recognition of income on the investment in direct financing lease under
U.S. GAAP, net of taxes on revenues		257,064		248,446		250,381
Reversal of depreciation recorded under Brazilian Accounting Principles		22,892		22,810		22,792
Pension and other benefits:
Difference in actuarial liability		5,992		2,479		8,460
Reversal of extraordinary item recorded under Brazilian Accounting Principles		-		49,288		49,288
Derivatives:
Adjustment to record derivative contracts at fair value — financial income (expense)		(11,875)		1,289		(9,897)
Amortization of loan guarantees — FIN 45		(5,595)		(3,805)		(3,288)
U.S. GAAP adjustments on equity in earnings of jointly-controlled subsidiaries		11,867		(41,262)		7,907
Deferred costs:
Operating expenses – amortization of preoperating expenses capitalized under Brazilian Accounting
Principles, net		1,078		6,693		5,164
Other		(2,085)		1,462		652
Deferred income and social contribution taxes effect on the above adjustments –		43,617		30,911		(4,152)
Effect of above adjustments on minority interest		(2,287)		(5)		5,451
Net income under U.S. GAAP		1,675,362		1,252,076		1,109,760
Other comprehensive income (loss) – post-retirement benefit obligation, net of tax effects		(6,184)		88,595		(2,444)
Comprehensive income under U.S. GAAP		1,669,178		1,340,671		1,107,316

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Earnings per share:
Weighted average number of common shares outstanding — basic		479,762,222		479,756,643		458,295,875
Basic earnings per share		3,492		2.610		2.421
Weighted average number of common shares outstanding — diluted		479,762,222		479,756,643		461,858,021
Diluted earnings per share		3.492		2.610		2.393

		2007		2006
Shareholders’ equity under Brazilian Accounting Principles		4,954,834		4,866,277
Capitalization of interest costs:
Reversal of capitalized interest under Brazilian Accounting Principles		(33,540)		(30,313)
Reversal of accumulated depreciation recorded under Brazilian Accounting Principles		18,370		17,838
Capitalization of interest under U.S. GAAP		215,926		183,452
Accumulated depreciation		(48,858)		(40,980)
Administrative costs capitalized under Brazilian Accounting Principles:
Reversal of capitalized administrative costs recorded under Brazilian Accounting Principles		(169,201)		(120,931)
Reversal of accumulated depreciation		18,865		11,987
Monetary restatement of 1996 and 1997:
Monetary restatement recorded under U.S. GAAP		12,826		12,856
Accumulated depreciation		(7,121)		(6,913)
Accounting for the effects of regulation:
Provision for expenditure on research and development and energy efficiency programs		-		(48,517)
Business combinations and goodwill:
Basis differences:
Property, plant and equipment – cost		985,417		884,252
Accumulated depreciation		(249,747)		(232,417)
Reversal of goodwill recorded under Brazilian Accounting Principles		(3,748,632)		(4,076,333)
Reversal of accumulated amortization		1,182,948		1,269,690
Recognition of concession intangible under U.S. GAAP		5,677,996		5,504,198
Recognition of goodwill under U.S. GAAP		7,777		-
Recognition of lease investment intangible under U.S. GAAP		488,677		488,677
Accumulated amortization		(1,659,330)		(1,430,952)
Reversal of tax benefit of the merged goodwill recorded under Brazilian Accounting Principles		(962,830)		(761,522)
Reversal of amortization of tax benefit of the merged goodwill recorded under Brazilian Accounting Principles .		147,016		100,991
Accounting for the leasing transactions:
Recognition of net investment in direct financing lease under U.S. GAAP		534,312		573,675
Reversal of property, plant and equipment recorded under Brazilian Accounting Principles		(942,394)		(939,918)
Reversal of accumulated depreciation		218,490		195,598
Pension and other benefits:
Difference in actuarial liability		251,345		254,760
Derivatives:
Adjustment to record derivative contracts at fair value		(12,843)		(968)
Accumulated amortization of loan guarantees — FIN 45		(14,406)		(8,811)
U.S. GAAP adjustments on equity interest in jointly-controlled subsidiaries consolidated proportionally
under Brazilian Accounting Principles		(23,749)		(35,616)
U.S. GAAP adjustments on investment at cost		(113,919)		-
Deferred costs:
Permanent assets — reversal of preoperating expenses capitalized under Brazilian Accounting Principles		(45,952)		(42,684)
Permanent assets — reversal of amortization of preoperating expenses capitalized under Brazilian Accounting
Principles		16,255		11,909
Reversal of proposed dividends		718,889		721,910
Founder shares		(5,237)		-
Other		(1,978)		432
Deferred income and social contribution taxes effect on the above adjustments		(595,632)		(540,798)
Effect of the above adjustments on minority interest		77,187		526
Shareholders’ equity under U.S. GAAP		6,891,761		6,781,355

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II – Statement of changes in shareholder’s equity in accordance with U.S. GAAP

		Year Ended December 31,
		2007		2006		2005
Shareholders’ equity under U.S. GAAP — beginning balance		6,781,355		6,271,133		5,178,325
Comprehensive income:
Net income for the year		1,675,362		1,252,076		1,109,760
Other comprehensive income (loss) – pension plan, net of tax
effects of R$ 3,197 (2006 – R$ 45,640 and 2005 – R$1,429)
and minority interest (2005 – R$ 329)		(6,184)		88,595		(2,444)
Comprehensive income		1,669,178		1,340,671		1,107,316
Capital increase		5,513		-		635,538
Treasury shares		-		8		(8)
Dividends and Interest on shareholders’ equity		(1,564,285)		(1,001,176)		(650,038)
Adjustment to other comprehensive income – related to pension
plan, net of tax effects of R$ 87,995 and minority interest of R$91		-		170,719		-
Shareholders’ equity under U.S. GAAP — ending balance		6,891,761		6,781,355		6,271,133
Accumulated other comprehensive income (expense), net of tax
effects of R$ 84,796 (2006 - R$ 87,995 and 2005 – R$ 45,640)
and minority interest of R$ 91 for 2006		164,602		170,719		(88,595)

In 2005, the additional minimum liability related to post-retirement benefit obligation was recognized in the other comprehensive income account. The remaning balance in 2005, in the amount of R$ 88,595 was recognized in the statement of income during 2006. Pursuant to the adoption of SFAS 158 – “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans”, as of December 31, 2006, the Company recognized an adjustment in the amount of R$ 170,719. In 2007, due to acquisition of RGE’s minority interest (see note 1), the Company acquired R$ 67 of its adjustment to other comprehensive income account, in addition to the R$ 6,184 recorded as expenses.

III – Description of GAAP differences

Following is a summary of the significant differences between Brazilian Accounting Principles and U.S. GAAP:

a) Capitalization of Interest Costs

Under Brazilian Accounting Principles, the Company capitalizes interest costs of borrowed funds only for those transaction in which it was established by contract the direct use of funds. Additionally, the Company has capitalized through December 31, 2001 inputed interest on shareholders’ funds applied to construction in progress.

Under U.S. GAAP, in accordance with SFAS No. 34, Capitalization of Interest Costs, interest incurred on borrowings is capitalized by the weighted average cost, to the extent that borrowings do not exceed construction in progress. Interest on shareholders’ funds are not capitalized. Under U.S. GAAP, the amount of interest capitalized excludes foreign exchange gains and losses on foreign currency borrowings.

b) Capitalization of Administrative Costs

Under Brazilian Accounting Principles, through March 31, 2002, the Company capitalized indirect administrative costs related to construction in progress, which had been allocated monthly to construction in progress, limited to 10% of direct expenses for personnel, and outside services attributable to construction in progress. As from 2005, administrative expenses are being capitalized by apportioning personnel expenses based on the time spent on the activities linked to the investments. This practice is not accepted under U.S. GAAP and consequently, the effects have been reversed in the U.S. GAAP reconciliation.

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c) Monetary restatement of 1996 and 1997

As mentioned in Note 2, under Brazilian Accounting Principles, the Company was required to discontinue accounting for the effects of inflation in Brazil as of December 31, 1995. As of January 1, 1996, the carrying value of all non-monetary assets and liabilities became their historical cost basis. Under U.S. GAAP, Brazil was still considered to be a highly inflationary economy until July 1, 1997, and consequently, the Company continued to record the effects of inflation using the Market General Price Index (IGP-M) up to 1997.

The U.S. GAAP income adjustment represents the depreciation of the monetary restatement and disposals of fixed assets, which resulted from the inflation accounting applied during 1996 and 1997.

d) Special Obligations

Special Obligations represent consumers’ contributions to the cost of expanding the electric power supply system, which are presented as a reduction to property, plant and equipment under Brazilian Accounting Principles. The assets acquired using the funds provided by consumers, or the assets provided to the Company by consumers under the regulations of Special Obligations are depreciated based on the respective assets’ useful lives, as established by ANEEL. According to ANEEL regulation up to 2006, Special Obligations were never subject to amortization.

Under U.S. GAAP, Special Obligations were considered a reimbursement of asset’s construction and/or acquisition costs and had been amortized since its contribution to the Company. The corresponding balance was presented reducing intangible asset (concession) when registered in the purchase accounting or, after the purchase accounting, reducing property, plant and equipment.

In 2006, through Normative Resolution No. 234, ANEEL established the general concepts, methodologies and procedures applicable to the second cycle of periodic tariff revisions for concessionaires engaged in the electric energy distribution services, which began in 2007.

This normative resolution modified the terms of the tariff rate setting process which, among other aspects, established that the fixed assets’ depreciation arising from assets acquired using funds provided by Special Obligations would no longer be considered as a component of the tariff to be granted to the concessionaire. According to the aforementioned regulation, the accounting treatment for Special Obligations under Brazilian Accounting Principles changed and, as from 2007, it is or will be amortized prospectively starting in the date of the next tariff revision for each distribution concessionaire.

As a consequence of this change in regulation, in 2006 the accounting treatment adopted under Brazilian Accounting Principles and U.S. GAAP, related to Special Obligations had to be aligned, and certain adjustments to the balances under U.S. GAAP related to Special Obligations were recorded in 2006, in order to reflect the new set of regulatory rules, as follows:

(i) The amount related to Special Obligations that had been amortized up to 2005, including the respective deferred taxes recognized in the purchase accounting, were reversed as a charge to the 2006 income statement. No amortization was recorded for 2006; and

(ii) The adjusted balance of Special Obligations (after amortization reversal), previously presented reducing intangible assets (concession), was reclassified reducing fixed assets.

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The details of these adjustments and reclassifications in 2006 are as follows:

Amounts adjusted to income statement in 2006:
Purchase accounting
Reversal of special obligations depreciation (recognized through intangible)		(70,189)
Reversal of special obligations depreciation (recognized through property, plant and
equipment)		(53,353)
Deferred taxes effect on the adjustments above		35,231
After purchase accounting
Reversal of special obligations depreciation (recognized through property, plant and
equipment)		(33,596)
Total amount adjusted in 2006:		(121,907)
Amounts reclassified as of December 31, 2006 to special obligation (after amortization reversal)
From intangible assets		353,660
From deferred taxes liabilities		(99,792)
		253,868
Special obligation, already recorded as a reduction of Property, plant and equipment		537,519
Balance of special obligation as of December 31, 2006		791,387

Accordingly, since Special Obligations’ amortization have been the same for Brazilian Accounting Principles and U.S. GAAP, no difference is recorded in the reconciliation note.

e) Accounting for the Effects of Regulation

Under U.S. GAAP, as a result of various actions taken by the Federal Government and ANEEL in 2001, and the enforcement of an Energy Rationing Program as described in note 3, the Company is subject to the provisions of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation”.

This Energy Rationing Program resulted in lower sales for the Company and in December 2001, electricity concessionaires including the Company reached an agreement with the Federal Government that provided resolution to the principal rationing related issues as well as to certain other electricity rate-related issues. As a result, an extraordinary tariff increase was established by the agreement, and will remain in effect during a period set by ANEEL.

Under Brazilian Accounting Principles, the Company recorded the entire amount to be recognized in accordance with this agreement. Under U.S. GAAP, pursuant to Emerging Issues Task Force (“EITF”) No. 92-7, “Accounting by Rate Regulated Utilities for the Effects of Certain Alternative Revenue Programs”, the Company records only the amount expected to be recovered over the next 24 months. The 2005 U.S.GAAP net income adjustments represents the reversal of the differences between the amounts recorded under Brazilian Accounting Principles and U.S. GAAP. As of December 31, 2005 the Company recorded all the RTE’s different effects of this accounting.

Additionally, the Company is obliged to invest, through its subsidiaries, 1% of the Net Operating Revenue in research and development and energy efficiency programs. This income is recorded on invoicing by the concessionaires, which also establish a provision in respect of expenditure not yet incurred for these programs, as mentioned in note 21.

A parcel of the amounts realized included amounts that were capitalized in the earlier years of the concession agreement. In accordance with U.S. GAAP, the provisions of SFAS 71 require recognition of the amount invoiced in income (loss) only when the expense incurred for these programs is recognized, including the effects of the amounts capitalized, so as to eliminate all the effects on the Company’s income (loss).

Accordingly, the US GAAP adjustment until 2006 refered to the reversal of the income corresponding to the expenditure capitalized with the research and development and energy efficiency programs, and was only recognized on amortization of these assets.

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During 2006 and 2007, several discussions were made by the distributions concessionaires and ANEEL regarding when research and development resources was inittially applied since it was only officially established after the first cycle of periodic tariff review which occurred in 2003. In its Official Letter No. 2,409/2007, ANEEL established additional guidelines and rules to be applied to 2007’s year ended closing, which made reference to the fact that research and development resources are those established through the tariff rate setting process.

Based in ANEEL’s Official Letter, the Company’s management considers that the amounts capitalized in the earlier years of the Concession were investments made by the Company, and the provisions recorded under U.S. GAAP should be completely reversed in 2007’s income statement. Accordingly, there are no differece between Brazilian Accounting Principles and U.S. GAAP regarding research and development and energy efficiency programs.

f) Comprehensive income

Brazilian Accounting Principles do not encompass the concept of Comprehensive income. Under U.S. GAAP, SFAS 130, “Reporting comprehensive income”, requires the disclosure of comprehensive income. Comprehensive income is comprised of net income and other comprehensive income that include charges or credits directly to equity. For U.S. GAAP reconciliation purposes, the amounts related to the difference between the pension plan fair value and the amount already recognized through the statement of income and the related deferred tax and minority interest effects that were recorded as adjustments directly to shareholders’ equity have been considered as other comprehensive income.

g) Business Combinations and Goodwill

Under Brazilian Accounting Principles, on the acquisition of subsidiaries the difference between the purchases price paid and the book value is recorded as goodwill, which is amortized on a straight-line basis over a ten-year period if supported by projections of future profitability. If the fair value of the property, plant and equipment of the acquired company exceeds the book value, the goodwill relating to this excess is amortized over the remaining useful lives of the related assets. Companies also have the option to amortize the goodwill over the remaining term of the related concession. If the goodwill does not fall into one of the above categories, it is written off. The acquirer is permitted to defer amortization of goodwill for several months until the acquired company become operational. The Company amortizes its goodwill proportionally to the future projected net income for the remaining term of the concession contract of each investee, as required by ANEEL.

Under U.S. GAAP, pursuant to SFAS 141, “Business Combinations” are accounted for by the purchase method of accounting. The cost of an acquired entity is allocated to assets acquired, including identifiable intangible assets and liabilities assumed based on their estimated fair values on the date of acquisition. The excess of the cost of an acquired entity over the net of the amounts assigned to assets acquired and liabilities assumed is recognized as goodwill. SFAS No. 141 requires disclosure of the primary reasons for a business combination and the allocation of the purchase price paid to the assets acquired and liabilities assumed by major balance sheet caption. SFAS No. 141 also requires that when the amounts of goodwill and intangible assets acquired are significant to the purchase price paid, disclosure of other information about those assets is required, such as the amount of goodwill by reportable segment and the amount of the purchase price assigned to each major intangible asset class. The Company allocated in its Intangible, the right to exploit the concession, which is calculated based on models that discount the concession’s future cash flows to present value. For all business acquisition, during the purchase price allocation, only R$ 7,777 was attributed to goodwill and recorded by the Company under U.S. GAAP.

Under Brazilian Accounting Principles, the Company recorded goodwill arising from the acquisition of subsidiaries as mentioned in note 13. Consequently, the U.S. GAAP adjustments represent the reversal of the goodwill and related amortization recorded under Brazilian Accounting Principles, and the recognition and amortization of the fair value adjustments as required by the purchase method.

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SFAS No. 142, “Goodwill and Other Intangible Assets,” (“SFAS No. 142”) — addresses financial accounting and reporting for acquired goodwill and other intangible assets. SFAS No. 142 addresses how intangible assets that are acquired individually or with a group of other assets (but not those acquired in a business combination) should be accounted for in financial statements upon their acquisition. This statement also addresses how goodwill and other intangible assets should be accounted for after they have been initially recognized in the financial statements. Under SFAS No. 142, goodwill is no longer subject to amortization over its estimated useful life, but rather it will be subject to at least an annual assessment for impairment by applying a fair-value-based test. Additionally, negative goodwill is recognized as an extraordinary gain at the time of the business combination after reducing to zero the amounts that otherwise would have been assigned to certain acquired assets.

The main business combinations occurred during 2006 and 2007, are as follows:

• 2006 – Acquisition of RGE and CPFL Santa Cruz

In June of 2006, the Company acquired from Public Service Enterprise Group (“PSEG”), 100% of the interest held in CPFL Serra (former Ipê Energia Ltda), CPFL Cone Sul (former PSEG Trader S.A.) and CPFL Missões (former PSEG Brasil Ltda). The total cost of acquisition was R$ 415,000.

The most significant asset acquired in this acquisition was the interest held by CPFL Serra in RGE, corresponding to 32.69% of RGE’s total capital. After a series of restructuring transaction, CPFL Missões and CPFL Serra were merged into RGE, as mentioned in note 1.

In December of 2006, the Company through its subsidiary Nova 4, acquired from Companhia Brasileira de Alumínio (“CBA”) 99.99% of the total capital of CPFL Santa Cruz. The total cost of acquisition was R$ 206,709.

The fair values of the assets acquired and liabilities assumed at the date of acquisition are summarized in the table below:

		CPFL		CPFL		CPFL		CPFL
		Serra		Cone Sul		Missões		Santa Cruz
Current assets		21,434		7,249		36		70,416
Investment in subsidiaries (a)		391,115		-		-		-
Property, plant and equipment		-		-		-		148,190
Intangible assets		-		-		-		61,758
Other assets		-		1,025		633		2,987
Total assets acquired		412,549		8,274		669		283,351
Current liabilities		2,519		2,420		-		45,724
Long-term liabilities		-		-		108		30,902
Total liabilities assumed		2,519		2,420		108		76,626
Net assets		410,030		5,854		561		206,725
Interest equity acquired		100%		100%		100%		99.99%
Net assets acquired		410,030		5,854		561		206,709
Total cost of acquisition		410,030		4,518		452		206,709

Under U.S. GAAP, the purchase price allocation did not result in the identification of any goodwill related to this acquisition.

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(a) Investment in subsidiaries:

In the acquisition date, as mentioned above, CPFL Serra held interest in RGE and Sul Geradora in the amount of R$ 391,060 and R$ 55, respectively. The fair value of RGE’s assets and liabilities at the acquisition date were summarized as follows:

		RGE
Current assets		492,445
Property, plant and equipment		1,043,551
Intangible assets (*)		458,431
Other assets		254,799
Total assets		2,249,226
Current liabilities		433,147
Long-term liabilities		619,810
Total liabilities		1,052,957
Net assets		1,196,269
Interest equity acquired		32.69%
Net assets acquired		391,060

(*) The purchase price allocation identified an intangible asset related to the right to explore RGE’s electric energy distribution concession.

• 2007 – Acquisition of CPFL Jaguariúna (former CMS Brasil)

As described in note 1, in June 2007, the Company acquired 100% of CPFL Jaguariúna’s total capital comprising of 94,810,080 common shares and 94,810,080 preferred shares. The total cost of this acquisition was USD 211 million which amounted to R$ 411,943 after currency translation and other direct costs.

Under U.S. GAAP, the Company has recorded such acquisition based on the fair value of the assets acquired and liabilities assumed in accordance with the purchase method of accounting pursuant to SFAS 141.

The fair values of the consolidated assets acquired and liabilities assumed at the acquisition date are summarized in the table below:

		CPFL
		Jaguariúna
Current assets		2,818
Noncurrent assets		766
Investment on subsidiaries (b)		418,941
Total assets acquired		422,525
Current liabilities		10,582
Long-term liabilities		-
Total liabilities assumed		10,582
Net assets acquired		411,943

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(b) Investment in subsidiaries:

		CPFL Leste		CPFL Sul		CPFL		CPFL		Jaguari		CPFL		CPFL
		Paulista		Paulista		Jaguari		Mococa		Geração		Planalto		Serviços		Total
Current assets		24,812		41,887		23,738		16,276		4,987		221		7,478		119,399
Noncurrent assets		15,572		18,988		12,928		5,754		4		-		814		54,060
Investment on subsidiaries		-		-		-		-		56,572		-		-		56,572
Property, plant and equipment		94,297		61,998		46,321		32,723		-		-		3,773		239,112
Intangible assets		18,355		55,164		28,749		19,726		-		-		-		121,994
Total assets acquired		153,036		178,037		111,736		74,479		61,563		221		12,065		591,137
Current liabilities		22,527		26,557		22,214		10,964		56		274		2,360		84,952
Long-term liabilities		19,114		15,004		9,894		5,973		-		-		26		50,011
Total liabilities assumed		41,641		41,561		32,108		16,937		56		274		2,386		134,963
Net assets		111,395		136,476		79,628		57,542		61,507		(53)		9,679		456,174
% acquired		93.20%		87.80%		90.15%		89.75%		90.15%		100.00%		89.81%
Net assets acquired		103,820		119,826		71,785		51,644		55,449		(53)		8,693		411,164
Purchase price paid		103,820		119,826		71,785		51,644		55,449		(53)		16,470		418,941
Goodwill		-		-		-		-		-		-		7,777		7,777

Under U.S. GAAP, the purchase price allocation for this acquisition resulted in the identification of R$ 7,777 related to the goodwill.

• Pro forma information (unaudited):

The following summary presents the Company’s unaudited pro forma consolidated statement of operations for the years ended December 31, 2007 and 2006, in accordance with Brazilian Accounting Principles, as if the acquisition of CPFL Jaguariúna, RGE and CPFL Santa Cruz had been completed at the beginning of each period.

		2007		2006
Operating revenues		14,408,453		13,176,633
Net operating revenues		9,544,244		9,566,695
Operating income		2,876,242		2,328,410
Net income		1,635,166		1,425,450
Earnings per share		3.407		2.971

The pro forma information is only presented for comparative purposes and does not intend to be indicative of what would have occurred had the acquisition actually been made at such date, nor is it necessarily indicative of future operating results.

h) Impairment of Long-lived Assets

Under Brazilian Accounting Principles, the carrying value of fixed assets are written down to realizable values when it is estimated that such assets will not be realized when compared to the results of future discounted cash flow projection. Under U.S. GAAP, Statement of Financial Accounting Standards (“SFAS”) No. 144, “Accounting for the Impairment of Long-lived Assets and Long-lived Assets to be Disposed of,” addresses accounting for the impairment of long-lived assets. Under SFAS 144, a provision for impairment is recorded against long-lived assets when there is an indication, based on a review of undiscounted future cash flows, that the carrying value of an asset or a group of assets may not be recoverable. No impairment has been recorded under U.S. GAAP for all periods presented.

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i) Accounting for Lease transactions

The adjustment under this caption is comprised mainly by the Serra da Mesa Lease Agreement. As described in Note 12, the Company has entered into a 30-year lease agreement relating to the Serra da Mesa power plant under which Furnas holds the concession and operates the plant, and is entitled to 49% of the related output. In exchange for the use of the plant, the Company receives 51% of the assured energy of the plant. The Company has entered into a 15-year sales agreement to sell back its parcel of the energy generated by the plant to Furnas for a fixed initial price, adjusted annually by inflation (IGP-M). Under Brazilian Accounting Principles, the lease is accounted for similar to an operating lease. Under U.S. GAAP, using the criteria set forth in SFAS No. 13, “Accounting for Leases,” the lease is classified as a direct-financing lease. Consequently, under U.S. GAAP, the power plant is removed from the Company’s financial statements and an investment in the lease is recorded. The unearned income is amortized to income over the lease term so as to produce a constant periodic rate of return on the net investment in the lease. The investment in the lease is adjusted annually for inflation. Therefore, the contingent rentals for 2007, 2006 and 2005 was R$ 180,846, R$ 169,803 and R$ 166,384, respectively. The assets relating to this lease are presented separately in Note 12.

Following are the components of the net investment for all leasing transactions:

		Year ended December 31,
		2007		2006
Net investment in direct financing lease – current		44,531		43,855
Net investment in direct financing lease – noncurrent		489,781		529,820
Total net investment in direct financing lease		534,312		573,675
Minimum lease payments receivable (*)		5,652,901		5,782,712
Less: Unearned income		(5,118,589)		(5,209,037)
Total net investment in direct financing lease		534,312		573,675

(*) At December 31, 2007, minimum lease payments for each of the five succeeding fiscal years are as follows: R$ 299,637 in 2008, R$ 298,818 in 2009, R$ 298,818 in 2010, R$ 298,818 in 2011 and R$ 299,637 in 2012

j) Pension and Other Benefits

Under Brazilian Accounting Principles, until December 31, 2000, pension plan and other benefits were recognized on a cash basis except for CPFL Paulista, CPFL Piratininga and CPFL Geração. With the enactment of CVM Resolution No. 371 of December 13, 2000, as of December 31, 2001, companies were required to record pension and post-retirement benefits on an accrual basis. As allowed by CVM Resolution No. 371/2000, the Company elected to record the parcel of actuarial liabilities in excess of plan assets as of December 31, 2001 over five years, ending on December 31, 2006.

Under U.S. GAAP, SFAS No. 87 “Employers’ Accounting for Pensions” and SFAS No. 106, “Employers’ Accounting for Post-retirement Benefits Other Than Pensions”, amended in 2006 by SFAS No. 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans" require recognition of costs on a more comprehensive accrual basis. Under SFAS No. 158, U.S. GAAP requires the recognition of either an asset or a liability, stated at fair value, for the difference between projected benefit obligations (as defined in SFAS No. 87 and SFAS No. 106) and plan assets, and all the changes in that funded status to be recognized through comprehensive income. SFAS No. 158 also establishes the measurement date of plan assets and obligations as the date of the employer's fiscal year end, and provides for additional annual disclosures. The disclosures required by SFAS No. 158 are presented in Note 35 (IV-a) below.

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k) Derivatives

As discussed in Note 31, in order to minimize its financing costs and to manage interest and exchange rate exposure, the Company enters into cross currency swap agreements to effectively convert a parcel of its foreign currency denominated variable-rate debt to Brazilian reais accruing interest at the CDI rate (Interbank deposit rate). Under Brazilian Accounting Principles, any differential to be paid or received under these contracts is recorded in an accrual basis as an asset or liability, with a corresponding adjustment to interest expense in the statement of income. The fair value of these contracts is not recognized in the consolidated financial statements.

Under U.S. GAAP, in June 1998, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards (SFAS) No. 133, “Accounting for Derivative Instruments and Hedging Activities.” SFAS No. 133, amended by SFAS No. 138, “Accounting for Certain Derivative Instruments and Certain Hedging Activities,” and SFAS No. 149, “Amendment of Statement 133 on Derivative Instruments and Hedging Activities,” establishes accounting and reporting standards requiring that all derivative instruments be recorded on the balance sheet as either an asset or liability and measured at fair value. SFAS No. 133 requires that changes in the derivative’s fair value be recognized currently in earnings unless specific hedge accounting criteria are met. Special accounting for qualifying hedges allows a derivative’s gains and losses to offset related results on the hedged item in the income statement, and requires that a Company must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. SFAS No. 133 must be applied to (a) derivative instruments and (b) certain derivative instruments embedded in hybrid contracts that were issued, acquired, or substantively modified after December 31, 1997.

Since the Company’s swap agreements do not qualify for hedging accounting, under U.S. GAAP, changes in fair value of these contracts have been recognized in earnings during 2007, 2006 and 2005.

l) Effect of guarantees recorded under FIN 45

Under Brazilian Accounting Principles, no specific pronouncement addresses the accounting requirements for guarantees. Therefore, the issuance of guarantees are not recorded in the financial statements.

Under U.S. GAAP, for guarantees issued the Company follows the Financial Interpretation No. 45, “Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others” (“FIN No. 45”). This interpretation requires certain disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under certain guarantees that it has issued. It also requires a guarantor to recognize, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee.

In February 2004, the investee CERAN obtained a loan from BNDES to exploit the hydroelectric potential of the Rio das Antas complex. The total loan obtained by CERAN, in the amount of R$ 435,805 was released by the financial institution in several tranches scheduled to be amortized by CERAN from December 2005 through January 2018. In June 2007, an amendment was sign in the original contract to finance Castro Alves and 14 de Julho projects, amounting to R$ 180,000 (R$ 117,000 in proportion to the participation of the subsidiary CPFL Geração), and have been released since July 2007. As of December 31, 2007, this total loan amounted to R$ 650,344. Although CPFL Geração has a 65% ownership interest in CERAN, CPFL Energia issued a guarantee for 100% of the loan. In exchange for this guarantee, the other shareholders reimburse CPFL Energia on a quarterly basis, proportionally to their respective ownership interest, an amount representing 1.5% per year of the average outstanding loan balance, paid on a quarterly basis. These payments are recorded as a financial income under Brazilian Accounting Principles. For this loan, in addition to the guarantee issued by CPFL Energia there are other guarantees given by CERAN shareholders’, such as the pledge of their shares and the rights emerging from the concession. In case of default, CPFL Energia may take judicial action against CERAN, and attempt to recover any amounts disbursed.

In April 2005, the investee ENERCAN obtained a loan from IDB to finance the Campos Novos Hydropower Plant. The loan obtained by ENERCAN, totaling US$ 75 million, is schedule to be amortized in 49 quarterly installments from June 2007. As of December 31, 2007, this loan amounted to R$ 129,703. Although CPFL Geração has a 48.72% ownership interest in the ENERCAN, the Company issued a guarantee for 57.27% of the loan. The effective date of this guarantee is up to the Project Completion Date.

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In September 2007, the investee Foz do Chapecó signed a loan agreement with BNDES to finance the Foz do Chapecó Hydropower Plant. The loan obtained by Foz do Chapecó, totaling R$ 1,655,838 (R$ 844,477 in proportion to the participation of CPFL Geração), will be released in several tranches. In December 31, 2007 the total amount released was R$ 480,000 (R$ 244,800 corresponding to CPFL Geração’s share). Although CPFL Geração has a 51% ownership interest in Foz do Chapecó, the Company issued a guarantee for 60% fo the loan up to the project completion date, which includes among other conditions, the power plant commercial start-up.

Under U.S. GAAP, the Company does not consolidate CERAN, ENERCAN and Foz do Chapecó, since the respective control is shared with other shareholders. Consequently, for U.S. GAAP purposes, pursuant to FIN No. 45, the Company is required to record a liability corresponding to the fair value of the guarantees issued amounting to R$ 48,170, R$ 3,036 and R$ 10,019 for CERAN, ENERCAN and Foz do Chapecó, respectively, which will be reduced through earnings as CPFL Energia is released from risk under the guarantee.

The offsetting entries were recorded as asset and are being realized through:

a) CERAN guarantee — (i) reimbursement to CPFL Energia by the other CERAN shareholders representing 35% ownership and; (ii) realization of the amount relating to the Company’s investment, which represents 65% ownership in CERAN.

b) ENERCAN guarantee — realization of the amount relating to the Company’s investment (48.72%) and the additional share (8.55%), as mentioned above, up to the Project Completion Date.

c) Foz do Chapecó guarantee — realization of the amount relating to the Company’s investment (51%) and the additional share (9%), as mentioned above, up to the Project Completion Date.

As of December 31, 2007, liabilities relating to the guarantees given to CERAN totaled R$ 43,351 (R$27,177 in 2006), and the assets amounted to R$ 31,981 (R$ 20,184 in 2006), of which R$ 20,212 (R$12,840 in 2006) refers to the costs of CPFL Energia and R$ 11,769 (R$ 7,344 in 2006) refers to the accounts receivable from the other CERAN shareholders.

As of December 31, 2007, liabilities relating to the guarantees given to ENERCAN and Foz do Chapecó totaled R$ 3,036 (R$ 3,036 in 2006) and R$ 10,019, respectively.

m) U.S. GAAP adjustments on equity in earnings of jointly-controlled subsidiaries

CERAN, ENERCAN, BAESA and Foz do Chapecó are accounted for using proportional consolidation under Brazilian Accounting Principles. Under U.S. GAAP, they are accounted for using the equity method of accounting. The U.S. GAAP basic adjustments are related to capitalized costs, the recognition of an intangible asset and a liability related to the use of a public asset during the time of the concession and derivative contracts. The effect of these adjustments is included as “U.S. GAAP adjustments on equity in earnings of jointly-controlled subsidiaries”, a line item in the reconciliations of net income (loss) and shareholders’ equity.

Up to May 2006, RGE and Sul Geradora were accounted for using proportional consolidation under Brazilian Accounting Principles, and by the equity method of accounting under U.S. GAAP. Since June 2006, when the Company acquired CPFL Serra and the control of RGE and Sul Geradora these subsidiaries became fully consolidated under Brazilian Accounting Principles and U.S. GAAP.

Under Brazilian Accounting Principles, property, plant and equipment under construction and in service of our jointly-controlled generation subsidiaries as of December 31, 2007 are as follows:

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								Foz do
Plants as of December 31, 2007		CERAN		Enercan		BAESA		Chapecó		Total
Property, plant and equipment in service		275,211		1,404,788		1,440,355		-		3,120,354
Accumulated depreciation		(18,891)		(31,734)		(67,945)		-		(118,570)
Net value		256,320		1,373,054		1,372,410		-		3,001,784
Plant under construction		731,512		80,575		2,065		517,440		1,331,592
Property, plant and equipment, net		987,832		1,453,629		1,374,475		517,440		4,333,376
Company’s share - %		65.00%		48.72%		25.01%		51.00%
Proportionate share in each plant		642,092		708,254		343,700		263,894		1,957,940

n) Deferred Costs

The Company has capitalized certain preoperating, research and development costs under Brazilian Accounting Principles. Under U.S. GAAP, these costs are recorded as expenses when incurred. The U.S. GAAP adjustment represents the reversal of deferred costs capitalized and the related amortization recorded under Brazilian Accounting Principles.

o) Income taxes

Under Brazilian Accounting Principles, deferred income tax liabilities are recognized based on the amount of future expected taxes to be paid. Deferred income tax assets related to deductible temporary differences or tax loss carryforwards are recognized when there is a reasonable certainty that the Company will generate profits against which it can offset such an asset. In addition, there are no expiration dates for the tax loss carryforwards.

Under U.S. GAAP, deferred income tax assets related to deductible temporary differences or tax loss carryforwards are recognized and, if necessary, a valuation allowance is recorded if it is more likely than not that such assets will not be realized.

According to U.S. GAAP, the Company has recorded additional deferred tax assets and liabilities for income tax and social contribution tax. The tax effects of temporary differences and tax loss carryforwards that give rise to significant portions of deferred tax assets and liabilities are presented below:

		As of December 31,
		2007		2006
Deferred tax asset under U.S. GAAP		784,696		650,114
Valuation allowance		(372,770)		(385,375)
Deferred tax asset, net of valuation allowance under U.S. GAAP		411,926		264,739
Deferred tax liability under U.S. GAAP		(490,911)		(368,521)
Net deferred tax liability under U.S. GAAP		(78,985)		(103,782)

The net decrease in the total valuation allowance for each of the years ended December 31, 2007, 2006 and 2005, was R$ 12,605, R$ 26,435 and R$ 56,787, respectively.

In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax-planning strategies in making this assessment. Based on the level of historical taxable income and projections for future taxable income over the periods for which deferred tax assets are deductible, management believes that it is more likely than not that the Company will realize the benefits of these deductible differences, net of existing valuation allowance at December 31, 2007. The amount of the deferred tax assets is considered realizable; however, could be reduced in the near term if estimates of future taxable income are reduced.

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The Company adopted the provisions of FIN 48 on January 1, 2007 and recognizes the effect of income tax positions only if those positions are more likely than not of being sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs. As a result of the implementation of FIN 48, the company did not record any further tax benefit related to uncertainty in income taxes, beyond those already recorded under Brazilian Accounting Principles (note 20). A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:

Balance at January 1, 2007		43,993
Increase related to prior year tax positions		-
Decrease related to prior year tax positions		-
Increase related to current year tax positions		8,407
Settlements		-
Balance at December 31, 2007		52,400

Included in the balance of total unrecognized tax benefits at December 31, 2007, are potential benefits of R$ 52,400 that, if recognized, would affect the effective rate on income from continuing operations.

The Company and its subsidiaries file federal income tax returns only in Brazil. For years before 2002, the Company is no longer subject to Brazilian federal income tax examinations. All income before taxes, minority interest and related income taxes are from Brazilian sources. The main lawsuits challenge by the Brazilian Revenue Service are described in note 20. Management, based on the opinion of the legal counsel, considers that there are no significant risks that are not covered by liabilities already recorded or that would result in a material change to its financial position or results of operations. The Company cannot predict that the total amounts of unrecognized tax benefits will significantly increase or decrease within the next 12 months.

The Company’s policy is to record penalties and interests related to unrecognized tax benefits as financial expenses in the consolidated statements of income. For the balance shown in the table above, the Company made escrow deposits waiting for the final decision by the Brazilian courts. Therefore the company is not subject to penalties and the interest expenses are offset by the monetary restatement applied to the judicial deposits.

p) Dividends Proposed

Under Brazilian Corporate Law, the Company is required to distribute at least 25% of its adjusted net income as a minimum mandatory annual dividend. The dividend that exceed the 25% minimum limit, may be proposed and accrued at each balance sheet date, but subject to the Annual Shareholders’ Meeting approval. Under U.S. GAAP, the dividends that exceeds the 25% minimum mandatory are recorded after the Annual Shareholders’ Meeting approval.

q) Founder shares

Under Paulista Lajeado shareholders’ agreement, in order to maintain an yield equal to 49.67% of Eletrobrás participation in the Paulista Lajeado’s net income, it is granted to this noncontrolling shareholder, securities represented by Founder Shares entitled to 10% of Paulista Lajeado’s net income before any other participation. These securites will be converted into preferred shares with no voting rights in 2032, at the end of concession. The conversion of the Founder Shares into Preferred Shares will correspond, at the time of conversion, to 5.084% of the total shares issued by Paulista Lajeado. Founders’ shares payments occur on the same dates as dividends or any other form of remuneration made to the Company’s shareholders.

Under Brazilian Accounting Principles, founders shares are registered as a shareholders’ equity reserve, at historical cost. Under U.S. GAAP, according to the provisions of SFAS 150 “ Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity”, those securities was classified as a liability and consequently have been measured at fair value.

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r) Earnings Per Share (“EPS”)

Under Brazilian Accounting Principles, net income per share is calculated on the number of shares outstanding at the balance sheet date. Subsequent changes in the Company’s share capital are not retroactively reflected in the disclosure of number of shares outstanding and in the calculation of earnings per share under Brazilian Accounting Principles. Under U.S. GAAP, the Company calculates earnings per share in accordance with SFAS No. 128, “Earnings Per Share.” Basic earnings per share is calculated by dividing net earnings available to common shares by average common shares outstanding during the period. For 2005, in connection with subscription rights granted to IFC, the Company had potentially dilutive securities outstanding. For 2007 and 2006, the Company has no potentially dilutive securities outstanding.

The computation of basic earnings per share is as follows:

		2007		2006		2005
Net income under U.S. GAAP		1,675,362		1,252,076		1,109,760
Weighted average number of common shares outstanding during
the period for basic EPS computation		479,762,222		479,756,643		458,295,875
Basic earnings per share – R$		3.492		2.610		2.421
The diluted earnings per share were calculated as follows:
		2007		2006		2005
Net income under U.S. GAAP		1,675,362		1,252,076		1,109,760
Adjusted for: 2005 – Interest expense and exchange rate
variation gains, net of taxes of 2,302		-		-		(4,470)
Net income under U.S. GAAP adjusted		1,675,362		1,252,076		1,105,290
Weighted average number of common shares		479,762,222		479,756,643		458,295,875
Plus: incremental weighted average shares from assumed
conversion of IFC loan		-		-		3,562,146
Weighted average number of common shares outstanding during
the period for diluted EPS computation		479,762,222		479,756,643		461,858,021
Diluted earnings per share – R$		3.492		2.610		2.393

s) Proportional Consolidation

As discussed in Note 2, under Brazilian Accounting Principles, the Company consolidates jointly-controlled subsidiaries using proportional consolidation. The Company’s investments accounted for using proportional consolidation are (i) CERAN, ENERCAN and BAESA for all periods presented, in which the Company holds a 65.00%, 48.72% and 25.01% interest share, respectively; (ii) FOZ DO CHAPECÓ, in which the Company increased its interest share in 2006 from 40% to 51% as described in note 1, and (iii) RGE and Sul Geradora until May 2006, in which the Company had a 67.07% and 67.23% ownership interest, respectively. Under U.S. GAAP, proportional consolidation is prohibited except in certain specific circumstances. Since the other shareholders’ interests in these jointly-controlled subsidiaries have substantive participating rights relation to, among others, (i) the approval of operating budgets, (ii) approval of transactions not provided for in the operating budget that exceed low threshold amounts, (iii) approval of the placement of executive officers, and (iv) approval of ordinary dividends, the Company would be precluded from consolidating these entities under U.S. GAAP and, consequently, these investments are accounted for using the equity method of accounting. This is a presentational difference only and does not affect the net income nor shareholders’ equity as determined under U.S. GAAP.

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Summarized balance sheet, statement of income and cash flow information for jointly-controlled subsidiaries of amounts proportionally consolidated in the Company’s Brazilian Accounting Principles financial statements is presented below:

		As of December 31,
		2007		2006
Current assets		434,439		80,292
Noncurrent assets		2,003,634		1,579,413
Net assets, eliminated in the consolidated(*)		(729,783)		(471,406)
Total assets		1,708,290		1,188,299
Current liabilities		324,350		169,437
Long-term liabilities		1,383,940		1,018,862
Total liabilities and shareholders’ equity		1,708,290		1,188,299

(*) Amount eliminated in the consolidated financial statement, related to the investment in jointly-controlled subsidiaries.

		Year ended December 31,
		2007		2006		2005
Operating revenues		269,067		775,460		1,483,445
Operating income		150,267		158,510		153,381
Cash flow provided by operating activities		89,435		97,219		75,742
Cash flow used in investing activities		(263,126)		(301,090)		(278,073)
Cash flow provided by financing activities		521,361		191,961		230,549

t) Escrow deposits

Under Brazilian Accounting Principles, the balances of escrow deposits are offset against the corresponding liability under the heading “Reserve for Contingencies” in long-term liabilities. Under U.S. GAAP, these balances are recorded gross as escrow deposits and reserve for contingencies. As a consequence, noncurrent assets and long-term liabilities under U.S. GAAP would be increased by R$ 158,876 and R$ 145,361 at December 31, 2007 and 2006, respectively. This difference has no net income or equity effect.

IV – SUPPLEMENTAL DISCLOSURES REQUIRED BY U.S. GAAP

a) Pension and Other Benefits

The disclosures required by SFAS 132 (Revised), Employer’s Disclosures about Pensions and Other Postretirement Benefits, SFAS 158 Employers’ Accounting for Defined benedit pension and Other Postretirement Plans and amendment of FASB Statements n. 87, 88 and 106 are presented below.

The following information does not consolidate the balances of RGE for 2005, since RGE, at that period, was proportionately consolidated under Brazilian Accounting Principles:

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Obligations and Funded Status

		As of December 31,
		2007		2006		2005
Change in benefit obligation (*)
Benefit obligation at beginning of year		3,150,340		3,049,416		2,970,087
Service cost		6,126		6,028		6,151
Interest cost		341,377		338,921		323,872
Actuarial gain		341,017		(127,644)		(29,817)
Benefits paid during the year		(241,237)		(234,326)		(220,877)
Benefit obligation added due to acquisition of RGE		-		117,945		-
Benefit obligation at end of year		3,597,623		3,150,340		3,049,416
Change in plan assets (*)
Fair value of plan assets at beginning of year		2,588,739		2,058,516		1,907,324
Actual return on plan assets		729,359		512,969		250,614
Participant’s contributions		2,551		1,823		2,116
Sponsor’s contributions		85,336		99,824		119,338
Benefits paid		(241,237)		(234,326)		(220,877)
Plan assets added due to acquisition of RGE		-		149,933		-
Fair Value of plan assets at end of year		3,164,748		2,588,739		2,058,515
Unfunded status at end of year		(432,875)		(561,601)		(990,900)

(*) The subsidiaries used a measurement date as of December 31, 2007, 2006 and 2005.

In 2007, the subsidiary RGE has a pension plan with funded status in the amount of R$ 33,952. To compose the consolidated amount, the remaining subsidiaries sponsor a defined benefit plan, which, as of December 31, 2007 have pension plans with unfunded status in the amount of R$ 466,827.

The book balances include other contributions relating to the Company’s plans amounting to R$ 36,305 (R$ 43,999 in 2006).

Amounts recognized in the statement of financial position consist of:

		As of December 31,
		2007		2006
Noncurrent assets		33,952		43,157
Long-term liabilities		(466,827)		(604,758)
Unfunded status		(432,875)		(561,601)

Information for pension plans with an accumulated benefit obligation in excess of plan assets:

		As of December 31,
		2007		2006		2005
Projected benefit obligation		3,597,623		3,150,340		3,049,416
Accumulated benefit obligation		3,582,665		3,137,743		3,039,991
Fair value of plan assets		3,164,748		2,588,739		2,058,515

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Components of Net Periodic Pension Cost

		As of December 31,
		2007		2006		2005
Service cost		(6,125)		(6,028)		(6,151)
Interest cost		(341,376)		(338,921)		(323,872)
Expected return on plan assets		392,038		350,264		244,760
Amortization of deferred gains, net		8,342		4,362		2,696
Net periodic benefit cost under U.S. GAAP		52,879		9,677		(82,567)
Net periodic benefit cost under Brazilian Accounting Principles		(46,887)		41,579		138,925
Less: Proportionate net periodic benefit income of RGE		-		511		1,390
U.S. GAAP adjustment to net income		5,992		51,767		57,748

Other changes in plan assets and benefit obligations recognized in accumulated other comprehensive income

		2007		2006		2005
Accumulated other comprehensive income at beginning of year		258,805		(134,235)		(137,491)
Decrease (increase) in additional minimum liability		-		134,235		(4,202)
Amounts recognized in net periodic benefit cost		(52,879)		-		-
Net actuarial gain (loss)		43,472		-		-
Other comprehensive income (loss) for the year		(9,407)		134,235		(4,202)
Additional minimum liability acquired from minority shareholders and
recorded as a reduction in liability		-		-		7,458
Adjustment related to the adoption of SFAS 158		-		258,805		-
Accumulated other comprehensive income at end of year		249,398		258,805		(134,235)

The components of the projected net periodic pension credit for 2008 are as follows:

Cost of service		(7,000)
Interest on actuarial liabilities		(356,370)
Expected return on plan assets		448,405
Amortization of deferred losses		3,337
Prior service cost		(14)
Expected participant contribution		1,570
Total income		89,928

Assumptions used were as follows:

		2007		2006 (*)		2005
Annual discount rate (**)		6%		6%		6%
Annual expected return on assets (**)		10%		11%		11%
Annual salary increase (**)		2%		2%		2%
Annual benefits adjustments (**)		0%		0%		0%
Long term inflation		4%		5%		5%

(*) In 2006, RGE used an annual discount rate of 6.0%, annual expected return on assets of 6.0%, an annual salary increase of 2.0% and a long term inflation of 3.2% .

(**) refers to real rate

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Plan Assets

The following table shows the distribution (per asset segment), as of December 31, 2007 and 2006, of the resources on which the CPFL Group benefits plan, managed by Fundação CESP, is secured. It also shows the distribution of the guaranteeing resources established as a target for 2008, obtained in the light of the macroeconomic prospects as of December 2007.

		As of December 31,				Target
						Allocation
		2007		2006		2008
Fixed income investments		71%		69%		72%
Stocks		25%		27%		25%
Real estate		2%		2%		1%
Other		2%		2%		2%
Total		100%		100%		100%

The allocation target for 2008, was based on the recommendations for allocation of assets made at the end of 2007 by Fundação CESP, in its Investment Policy. This target may change at any time during 2008, in the light of changes in the macro-economic situation or in the return on assets, among other factors.

Brazilian pension funds are subject to restrictions on investments in foreign assets. The major part of the resources of the Company’s pension plans is invested in the fixed income segment and, within the segment, the greater part of the funds is invested in public federal bonds, indexed to the IGP, which is the index for adjusted of the actuarial liabilities of the Company’s plans (defined benefit plans).

The pension plans are monitored by the Company’s Pensions Management Committee, which includes representatives of active and retired employees, as well as members appointed by the Company. Among the duties of this Committee are the analysis and approval of investment recommendations made by the investment managers of the Fundação CESP.

The objective of the asset management performed by Fundação CESP is to maximize the return on investments, but always seeking to reduce to a minimum the risks of actuarial deficit. Therefore, investments are always made bearing in mind the liabilities that have to be honored. One of the main tools used by Fundação CESP to achieve its management objectives is ALM (Asset Liability Management – Joint Management of Assets and Liabilities), performed at least once a year, for a horizon of more than 10 years. The ALM also assists in studying the liquidity of the pension plans, taking into consideration the benefit payment flow in relation to liquid assets.

In addition to controlling market risks by the unplanned divergence methodology, as required by law, the Fundação CESP uses the following tools to control market risks in the fixed income and variable income segments: V@R, Tracking Risk, Tracking Error and Stress Test.

The Fundação CESP Investment Policy imposes additional restrictions, which, together with those already laid down by law, define the percentages of diversification for investments in assets issued by or with joint liability with a single legal entity to be used internally. We set forth below some additional restrictions in relation to the limitations on diversification of investments:

a) Investments in any bonds or marketable securities issued by a single legal entity – financial institution or otherwise — by the parent company, companies directly or indirectly controlled by the entity and associated or other companies under control, may not jointly exceed 10% (ten percent) of the resources guaranteeing each Pension Plan, including not only those purchased on a permanent basis, but also those loaned and subject to purchase and sale agreements and those forming part of the portfolios of funds in which the Pension Plans participate, through Fundacao CESP, in proportion to their respective participations.

b) In the case of investments in marketable securities issued by or with the joint responsibility of a financial or other institution authorized by the Brazilian Central Bank, and of savings deposits, the total issued, and the joint liability or responsibility of a single institution may not exceed: (i) 25% of the shareholders’ equity of the issuer, in the case of an institution classified as having a low credit risk and 15% of the Fixed Income segment, in the same case; (ii) 10% of the shareholders’ equity of the issuer, in the case of an institution classified as having a medium or high credit risk and 10% of the Fixed Income segment, in the same case;

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c) The total investments in shares of a single company may not exceed: (i) 20% of its voting capital; (ii) 20% of its total capital and (iii) 5% of the total resources guaranteeing each Pension Plan, with the option to increase this limit up to 10% in the case of shares corresponding to 3% or more of IBOVESPA, IBX or FGV-100

As of December 31, 2007 the pension plan assets includes R$ 181,954 (R$ 166,447 as of December 31, 2006) of equity securities issued by the Company.

Cash flows

Contributions

The Company expects to contribute R$ 68,768 to its pension plan in 2008.

Expected Benefits

Estimated future benefit payments are as follows:

2008		244,029
2009		256,006
2010		268,303
2011		283,221
2012		299,910
2013 to 2017		1,789,077

b) Intangible assets

Following is a summary of the Company’s intangible assets recorded under U.S. GAAP:

		2007		2006
Concession intangibles		5,677,996		5,504,198
Lease investment intangible		488,677		488,677
Accumulated amortization as of December 31, 2007		(1,659,330)		(1,430,952)
Intangibles, net		4,507,343		4,561,923
Weighted average remaining amortization period (years)		20		21

Intangibles are amortized on a straight-line basis. Consequently, aggregate amortization for the next five years will amount to R$ 236,419 per year.

c) Segment Information

The Company’s operating segments are organized internally primarily by legal entity, and in accordance with SFAS No. 131, “Disclosures about Segments of an Enterprise and Related Information,” the Company has aggregated similar operating segments into three reportable segments: Distribution, Generation and Commercialization. The distribution, generation and commercialization activities of the Company are described in Note 1.

The Company evaluates segment performance and allocates resources based on several factors, of which revenues and operating income are the primary financial measures. The accounting policies of the reportable segments are the same as those described in the Note 2. Following is the Company’s segment information presented in accordance with Brazilian Accounting Principles.

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		Distribution		Generation		Commercialization		Other (*)		Eliminations		Total
2007
Revenues		12,985,618		329,227		892,539		-		-		14,207,384
Intersegment revenues		11,557		371,990		985,397		-		(1,368,944)		-
Operating income (loss) (i) .		2,083,462		465,826		353,109		(24,494)		-		2,877,903
Income before income taxes		-		-		-		-		-		2,476,655
Net income												1,643,436
Total assets (**)		11,067,761		3,851,208		255,772		421,028		-		15,595,769
Capital expenditures		680,267		445,334		7,082		74		-		1,132,757
Depreciation and amortization (ii)		469,888		76,785		1,388		100		-		548,161
2006
Revenues		11,249,034		282,091		695,927		-		-		12,227,052
Intersegment revenues		7,980		224,132		1,138,196		-		(1,370,308)		-
Operating income (loss) (i) .		1,645,063		369,807		275,760		(18,913)		-		2,271,717
Income before income taxes
and extraordinary item		-		-		-		-		-		2,171,091
Net income												1,404,096
Total assets		10,388,503		3,173,930		180,891		305,457		-		14,048,781
Capital expenditures		526,954		265,881		4,295		105		-		797,235
Depreciation and amortization (ii)		406,502		67,962		242		9		-		474,715
2005
Revenues		10,100,010		305,557		501,491		-		-		10,907,058
Intersegment revenues		680		130,350		918,314		-		(1,049,344)		-
Operating income (loss) (i) .		1,143,736		283,562		224,629		(9,327)		-		1,642,600
Income before income taxes
and extraordinary item		-		-		-		-		-		1,430,541
Net income		-		-		-		-		-		1,021,278
Total assets		10,261,520		2,916,056		156,789		517,077		-		13,851,442
Capital expenditures		368,012		254,863		3,525		137		-		626,537
Depreciation and amortization (ii)		367,533		60,318		107		-		-		427,958

(i) Operating income for the commercialization segment includes the effect of intersegment transactions that has not been eliminated for the purposes of this segment presentation. The commercialization intersegment transaction are principally with the distribution segment.

(ii) From the total amount of depreciation and amortization described above R$ 206,669 as of December 31, 2007, R$ 177,233 in 2006 and R$ 154,804 in 2005 is classified as Operating Expenses which is comprised of R$ 176,306 (R$ 151,844 in 2006 and R$ 125,709 in 2005) related to Amortization of Goodwill and R$ 30,363 (R$ 25,389 in 2006 and R29,095 in 2005) related to sales, marketing, general and administrative expenses (note 25).

(*) Refers to investment in other subsidiaries that act as a holding company.
(**)The goodwill created in an acquisition, net the amortization, recorded in CPFL Energia was allocated to the respective segments.

d) Income Statement Classification Differences

Under Brazilian Accounting Principles, the Company has classified the amortization of the increase in pension liability that was recorded when the Company adopted CVM Resolution No. 371 as an extraordinary item (note 20). Under U.S. GAAP, this item is classified as an operating expense.

Under Brazilian Accounting Principles, the Company classifies gains and losses on disposals of permanent assets (mainly property, plant and equipment), materials and, write off of feasibility studies as non-operating income or expense. Under U.S. GAAP, these items are classified as operating income or expense.

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e) Reconciliation of operating income and total assets

The reconciliation between the balances as per the Brazilian Accounting Principles and U.S. GAAP for operating income and total assets for the years presented is as follows:

		Year ended December 31
		2007		2006		2005
Operating income under Brazilian Accounting Principles		2,877,903		2,271,717		1,642,600
Less: jointly-controlled subsidiaries proportionally consolidated		(150,266)		(158,510)		(153,381)
Reclassification of items recorded as nonoperating under Brazilian
Accounting Principles considered as operating under U.S. GAAP
(excluded RGE, while recorded under the equity method):
Gain on disposal of permanent assets		2,281		2,203		9,308
Materials and supplies overages and other		768		1,955		304
Loss on disposal of permanent assets		(29,349)		(16,096)		(2,483)
Write off of feasibility studies		(5,914)		(754)		(15)
Materials and supplies shrinkage and other		(1,721)		(3,908)		(235)
Depreciation and disposal of interest costs capitalized		(7,569)		(4,267)		(4,901)
Capitalization of administrative costs		(41,233)		(38,554)		(12,421)
Depreciation and disposal of monetary restatement 1996 and 1997		(238)		(234)		(1,779)
Depreciation of special obligation		-		(33,596)		16,381
Accounting for the effects of regulation
Extraordinary tariff adjustment		-		-		82,695
Provision for expenditure on research and development and
energy efficiency programs		48,517		10,071		(21,093)
Business combinations and goodwill:
Basis differences:
Depreciation of basis difference in property, plant and equipment		539		(48.225)		(20,598)
Effect of disposal of property, plant and equipment		(13,081)		(14.063)		(8,724)
Reversal of goodwill amortization under Brazilian Accounting Principles		176,306		147,645		117,561
Amortization of intangible concession assets under U.S. GAAP		(209,761)		(261,445)		(185,040)
Amortization of intangible lease agreement under U.S. GAAP		(18,616)		(18,616)		(18,616)
Accounting for the leasing transactions:
Operating revenues		(41,839)		(25,034)		(48,295)
Operating costs		22,892		22,810		22,792
Pension and other benefits		5,992		2,479		8,460
Deferred costs		1,078		6,693		5,164
Other		35		-		653
Operating income under U.S. GAAP		2,616,724		1.842.271		1,428,337

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		As of December 31,
		2007		2006
Total Assets under Brazilian Accounting Principles		15,595,769		14,048,781
Less jointly-controlled subsidiaries proportionally consolidated assets in excess of the
respective investments by the equity method		(1,708,290)		(1,188,299)
Escrow deposits, presented net against reserve for contingencies under Brazilian
Accounting Principles		158,876		145,361
Capitalization of interest costs		151,898		129,997
Administrative costs capitalized under Brazilian Accounting Principles		(150,336)		(108,944)
Monetary restatement of 1996 and 1997		5,705		5,943
Business combinations and goodwill
Basis differences
Tax benefit of merged goodwill, net of income tax effect		(815,814)		(660,531)
Property, plant and equipment		735,670		651.835
Reversal of goodwill recorded under Brazilian Accounting Principles		(2,565,684)		(2,806,643)
Recognition of goodwill under U.S. GAAP		7.777		-
Recognition of concession intangible under U.S. GAAP		5,677,996		5,504,198
Recognition of lease investment intangible under U.S. GAAP		488,677		488,677
Accumulated amortization		(1,659,330)		(1,430,952)
Accounting for the leasing transactions:
Recognition of net investment in direct financing lease under U.S. GAAP		534,312		573,675
Reversal of property, plant and equipment recorded under
Brazilian Accounting Principles		(723,904)		(744,320)
Prepaid pension cost		30,433		43,157
Derivative contracts		(994)		(204)
Receivables and costs related to guarantees granted to CERAN, ENERCAN and
Foz do Chapecó		42,000		21,342
U.S. GAAP adjustments on equity interest in jointly-controlled subsidiaries		(23,749)		(35,616)
U.S. GAAP adjustments on investment at cost		(113,919)		-
Deferred costs		(29,697)		(30,775)
Other		(291)		431
Deferred income tax effects		(104,721)		(172,277)
Total Assets under U.S. GAAP		15,532,384		14.434,836

The detailed description of the nature of each adjustment in the above reconciliation is included in the previous topics of this note.

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f) Statements of cash flows

The consolidated statements of cash flows for each of the three years in the period ended December 31, 2007 are presented in accordance with the presentational format determined by U.S. GAAP using amounts determined under Brazilian Accounting Principles.

		2007		2006		2005
NET INCOME		1,643,436		1,404,096		1,021,278
ADJUSTMENT TO RECONCILE NET INCOME TO CASH PROVIDED
BY OPERATING ACTIVITIES
Minority interest		5,194		173		40,371
Monetary restatement of rationing regulatory assets		(85,333)		(108,391)		(243,800)
Provision for losses on realizing the Extraordinary Tariff Recovery		9,735		1,038		91,805
Differential - 2003 tariff review		62,938		(138,825)		(1,031)
Tariff adjustment 2005 and 2006		18,950		6,217		(11,043)
Regulatory assets – other		28,148		(5,231)		(73,545)
Low income subsidy		(13,934)		(23,835)		(21,329)
Depreciation and amortization		548,161		474,714		427,958
Reserve for contingencies		12,062		(86,117)		74,494
Interest and monetary restatement		(96,424)		(23,775)		(10,651)
Unrealized (gains) loss on derivative contracts		101,981		(919)		(21,833)
Post-retirement benefit obligation		(46,887)		38,026		124,853
(Gain) loss on disposal of permanent assets and participation in
subsidiaries		24,288		(35,969)		156
Recognition of tax benefits		48,444		82,610		(63,146)
Research and Development and Energy Efficiency Programs		(6,570)		27,411		49,319
Other		2,274		(1,023)		3,845
DECREASE (INCREASE) IN OPERATING ASSETS
Financial investments		(88,525)		260,575		(32,575)
Accounts receivable		273,006		265,306		174,171
Recoverable taxes		30,308		34,193		(22,302)
Deferred cost variations		171,264		204,357		123,652
Escrow deposits		(400,547)		(38,171)		(78,704)
Other		(37,268)		29,089		(8,871)
INCREASE (DECREASE) IN OPERATING LIABILITIES
Suppliers		1,149		(90,378)		251
Taxes and payroll charges payable		62,561		4,451		(7,468)
Deferred gain variations		57,451		2,666		78,995
Post-retirement benefit obligation		(93,226)		(104,715)		(109,896)
Interest on debts — accrued		1,588		(36,380)		44,158
Loan and financing — interest added to the principal		27,146		70,105		58,780
Regulatory charges		(39,162)		68,082		(30,559)
Other		25,359		18,736		10,956
NET CASH PROVIDED BY OPERATING ACTIVITIES		2,247,567		2,298,116		1,588,289

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						(Continued)
		2007		2006		2005
INVESTING ACTIVITIES
Purchase of interest of subsidiaries, net of cash		(383,816)		(593,000)		(5,424)
Additions to permanent assets		(1,132,757)		(797,235)		(626,537)
Financial investments		(51,520)		(18,916)		(157,967)
Proceeds from sales of financial investments		33,549		27,847		11,696
Special obligations		65,917		49,426		23,371
Additions to deferred charges		(8,536)		(12,733)		(5,433)
Proceeds from sale of permanent assets		24,091		94,308		18,261
Other		(28,378)		(81)		(2,387)
NET CASH USED IN INVESTING ACTIVITIES		(1,481,450)		(1,250,384)		(744,420)
FINANCING ACTIVITIES
Loans and financing obtained		2,551,090		2,124,163		1,124,359
Payments of loans and financing		(1,451,590)		(2,220,076)		(1,230,116)
Dividends and interest on shareholder’s equity paid		(1,560,952)		(1,090,259)		(559,170)
Capital increase		271		-		-
Advance for future capital increase		82,597		-		-
Other		-		24		-
NET CASH USED IN FINANCING ACTIVITIES		(378,584)		(1,186,148)		(664,927)
INCREASE IN CASH AND CASH EQUIVALENTS		387,533		(138,416)		178,942
CASH AND CASH EQUIVALENTS — BEGINNING OF YEAR		540,364		678,780		499,838
CASH AND CASH EQUIVALENTS — END OF YEAR		927,897		540,364		678,780
SUPPLEMENTAL CASH FLOWS DISCLOSURES:
Taxes paid in cash for the year		477,972		452,896		369,825
Interest paid in cash for the year		331,252		490,965		462,882
TRANSACTIONS NOT AFFECTING CASH:
Conversion of debt into Capital (IFC Subscription Bonus)		-		-		98,976
Acquisition of minority shareholders with share issue		6,385		-		553,778
Business acquisition:
Assets acquired, including goodwill		605,998		1,051,768		5,608
Liabilities assumed		(191,897)		(424,441)		(4)
Purchase price paid		414,101		627,327		5,604
Cash acquired		(30,285)		(34,327)		(180)
Purchase price, net of cash acquired		383,816		593,000		5,424

g) New Accounting Pronouncements

In September 2006, the FASB issued SFAS No. 157, “Fair Value Measurement”. This statement defines fair value, establishes a framework for the measurent of fair value, and enhances disclosures about fair value measurements. This Statement is effective for fiscal years beginning after November 15, 2007. The Company is currently evaluating the impact of adopting of this Statement. FASB Staff Position 157-2 delays the effective date of FASB Statement No. 157, Fair Value Measurements, for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). The delay is intended to allow the Board and constituents additional time to consider the effect of various implementation issues that have arisen, or that may arise, from the application of Statement 157. The company is currently evaluating the impact of adopting of this Statement.

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In February 2007, the FASB issued SFAS No. 159 – “The Fair Value Option for Financial Assets and Financial Liabilities”, which permits entities to choose to measure many financial intruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. Accordingly, this Statement does not require any new fair value measurements. This Statement is effective for financial statements issued for fiscal years beginning after November 15, 2007 and interim periods within those fiscal years. This statement has no impact in the Company’s consolidated financial statements.

In December 2007, the FASB issued SFAS No. 141R, “Business Combinations” and SFAS No. 160, “Noncontrolling Interests in Consolidated Financial Statements” – an amendment to ARB No. 51. These statements require most identifiable assets, liabilities, noncontrolling interests, and goodwill acquired in a business combination to be recorded at “full fair value” and require noncontrolling interests to be reported as a component of equity, which changes the accounting for transactions with noncontrolling interest holders. Both Statements are effective for fiscal years beginning after December 15, 2008, and earlier adopted is prohibited. The Company is currently evaluating the impact of adopting of these Statements.

In March 2008, FASB issued SFAS 161 “Disclosure about derivative instruments and hedging activities”. This statement amends and expands the disclosure requirements of Statement 133 Accounting for Derivative Instruments and Hedging Activities, with the intent to provide users of financial statements with an enhanced understanding of (a) how and why an entity uses derivative instruments; (b) how derivative instruments and related hedged items are accounted for under Statement 133 and its related interpretations (c) how derivative instruments and related hedged items affect an entity’s financial position, financial performance, and cash flows. To meet those objectives, SFAS 161 requires qualitative disclosures about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of and gains and losses on derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. The company is currently evaluating the impact of adopting of this Statement.

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CONDENSED UNCONSOLIDATED FINANCIAL INFORMATION OF CPFL ENERGIA S.A.

The condensed unconsolidated financial information of CPFL Energia S.A., as of December 31, 2007 and 2006 and for each of the three years in the period ending on December 31, 2007, under Brazilian Accounting Principles is as follows:

BALANCE SHEETS AS OF DECEMBER 31, 2007 AND 2006 (UNCONSOLIDATED)
(In thousands of Brazilian reais)

		2007		2006
ASSETS
CURRENT ASSETS
Cash and cash equivalents		5,744		25,429
Financial investments		46,614		29,579
Recoverable taxes		31,899		28,655
Deferred taxes		10,107		9,951
Dividends receivable		1,008,363		824,242
Other		5,059		351
		1,107,786		918,207
NONCURRENT ASSETS
Financial investments		97,521		103,901
Recoverable taxes		2,787		2,787
Deferred taxes		79,038		70,997
Advance for future capital increase		409,310		-
Other		6,892		307
		595,548		177,992
PERMANENT ASSETS
Investments in subsidiaries		3,077,514		3,126,322
Goodwill		1,654,718		1,448,410
Property, plant and equipment		467		493
Other		6,412		1,048
		4,739,111		4,576,273
TOTAL ASSETS		6,442,445		5,672,472

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BALANCE SHEETS AS OF DECEMBER 31, 2007 AND 2006 (UNCONSOLIDATED)
(In thousands of Brazilian reais)

		2007		2006
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Suppliers		14,029		6,387
Accrued interest on loans, financing and debentures		15,983		120
Loans and financing		-		8,286
Taxes and payroll charges payable		273		291
Dividends and interest on shareholders’ equity		730,634		726,798
Derivative		22		40,141
Other		1,310		954
		762,251		782,977
LONG-TERM LIABILITIES
Reserve for contingencies		43,691		23,218
Derivative		47,913		-
Accrued interest on debts		12,505		-
Loans and financing		171,251		-
Debentures		450,000		-
		725,360		23,218
SHAREHOLDERS’ EQUITY
Common stock without par value (2007 – 479,910,938 issued and
outstanding; 2006 – 479,756,730 issued and outstanding)		4,741,175		4,734,790
Capital reserves		16		16
Profit reserves		213,643		131,471
		4,954,834		4,866,277
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY		6,442,445		5,672,472

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STATEMENTS OF INCOME FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005 (UNCONSOLIDATED)
(In thousands of Brazilian reais)

		2007		2006		2005
OPERATING EXPENSES
General and administrative expenses		(24,475)		(18,934)		(9,327)
Amortization of goodwill		(111,798)		(86,438)		(56,134)
		(136,273)		(105,372)		(65,461)
EQUITY IN EARNINGS OF INVESTEES		1,856,969		1,448,943		916,818
FINANCIAL EXPENSE
Financial income		21,070		86,136		47,316
Financial expense		(74,847)		(38,170)		(23,457)
		(53,777)		47,966		23,859
NONOPERATING INCOME (EXPENSES)
Nonoperating income		3,309		62,747		9
Nonoperating expense		(4,185)		(2,398)		(658)
		(876)		60,349		(649)
SOCIAL CONTRIBUTION AND INCOME TAX
Social contribution tax
Current tax		(5,998)		(12,837)		-
Deferred tax		(1,367)		4,297		13,000
Income tax
Current tax		(24,805)		(43,902)		(160)
Deferred tax		9,563		4,652		59,000
		(22,607)		(47,790)		71,840
NET INCOME FOR THE YEAR		1,643,436		1,404,096		946,407

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STATEMENTS OF CHANGES IN CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005 (UNCONSOLIDATED)
(In thousands of Brazilian reais)

		2007		2006		2005
NET CASH PROVIDED BY (USED IN) OPERATING
ACTIVITIES		1,471,854		1,243,359		687,332
INVESTING ACTIVITIES
Purchase of interest in subsidiaries		(2,582)		(415,000)		(2,837)
Return of capital invested in subsidiary		12,400		20,628		-
Increase in property, plant and equipment		(74)		(101)		(137)
Financial investments		-		-		(130,615)
Proceeds from sales of financial investments		31,045		24,754		11,696
Additions to deferred charges		(6,136)		(335)		(204)
Sale of equity interest		2,635		89,899		-
Advance for future capital increase		(409,368)		-		-
Other		-		(300)		-
NET CASH USED IN INVESTING ACTIVITIES		(372,080)		(280,455)		(122,097)
FINANCING ACTIVITIES
Loans and financing obtained		916,250		14,082		-
Payments of loans and financing		(473,250)		-		-
Dividends paid		(1,557,428)		(1,089,653)		(529,282)
Other		(5,031)		24		-
NET CASH USED IN FINANCING ACTIVITIES		(1,119,459)		(1,075,547)		(529,282)
INCREASE IN CASH AND CASH EQUIVALENTS		(19,685)		(112,643)		35,953
CASH AND CASH EQUIVALENTS – BEGINNING OF YEAR		25,429		138,072		102,119
CASH AND CASH EQUIVALENTS — END OF YEAR		5,744		25,429		138,072

Following is information relating to CPFL Energia’s unconsolidated condensed financial statements presented above:

• Nonoperating Income — In 2006, the Company sold equity interest held for investments.

• Deferred Taxes — As of December 31, 2005 CPFL Energia recorded part of the tax credits referring to tax loss carryforwards, based on expectations of future taxable income for income tax and social contribution.

• Investments — As of December 31, 2007 and 2006, investments in subsidiaries are comprised as follows:

		2007			2006
CPFL Paulista		497,388	(*)		1,456,044
CPFL Piratininga		230,538			230,538
RGE		1,097,275	(*)		-
CPFL Santa Cruz		120,124			-
CPFL Geração		1,128,591			1,114,590
CPFL Brasil		3,598			547
CPFL Serra		-			320,607
CPFL Cone Sul		-			5,519
Nova 4		-			(1,523)
		3,077,514			3,126,322

(*) As described in note 1, during 2007 CPFL Paulista transfered the share control of RGE through a capital reduction and, after a sequence of corporate reestrucring, RGE became a wholly-owned subsidiary of CPFL Energia.

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• Goodwill — As of December 31, 2007 and 2006, goodwill is comprised as follows (for additional information, see note 13):

		2007		2006
CPFL Paulista		1,110,960		1,196,403
CPFL Piratininga		135,683		145,410
CPFL Geração		46,519		49,867
RGE		302,560		-
CPFL Santa Cruz		58,970		-
CPFL Serra		-		58,176
CPFL Cone Sul		-		(1,337)
CPFL Missões		-		(109)
Other		26		-
		1,654,718		1,448,410

• Debentures: On October 25, 2007, the company issued debentures in the amount of R$ 450,000. This issuance is part of the Company's fund-raising strategy to finance the acquisition of CPFL Jaguariúna.

• Reserve for contingencies — CPFL Energia recorded a reserve for contingencies related to the non-payment of PIS and COFINS levied on interest on shareholders’ equity.

• Dividends received — The dividends received are comprised as follows:

		2007		2006		2005
CPFL Paulista		741,408		665,733		591,410
CPFL Piratininga		361,964		104,850		170
CPFL Serra		110,467		-		-
CPFL Cone Sul		1,297		-		-
CPFL Geração		153,822		167,032		-
CPFL Brasil		206,913		184,748		128,125
CPFL Santa Cruz		12,183		-		-
		1,588,054		1,122,363		719,705

• Restriction of transfer of funds from subsidiaries – CPFL Paulista, CPFL Piratininga, RGE, CPFL Geração, CPFL Santa Cruz, ENERCAN, CERAN, BAESA, Foz do Chapecó, CPFL Sul Centrais Elétricas, CPFL Leste Paulista, CPFL Jaguari, CPFL Sul Paulista and CPFL Mococa qualify as concessionaires of public services. As such, any transfer of funds to the respective parent company, in the form of loans or advances, requires approval by ANEEL.

As of December 31, 2007, total restricted subsidiaries net assets amount to R$ 3,963,568 composed as follows:

CPFL Paulista		497,388
CPFL Piratininga		230,538
RGE		1,097,275
CPFL Santa Cruz		120,124
ENERCAN, CERAN, BAESA and Foz do Chapecó		729,783
CPFL Sul Centrais Eletricas		3,730
CPFL Geração		1,128,591
CPFL Leste Paulista, CPFL Jaguari, CPFL Sul Paulista, CPFL Mococa		156,139
		3,963,568

This regulatory restriction does not apply to cash dividends determined in accordance with the Brazilian corporate law. However, as described in Notes 16 and 17, CPFL Paulista, CPFL Piratininga, RGE, ENERCAN, CERAN and BAESA may have restrictions relating to the payment of dividends.

F - 95

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(A free translation from the original issued in Portuguese)

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders
Rio Grande Energia S.A.

1. We have audited the accompanying consolidated balance sheet of Rio Grande Energia S.A. and subsidiary as of December 31, 2006, and the related consolidated statements of operations, of changes in stockholders’ equity and of changes in financial position for each of the two years in the period ended December 31, 2006. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

2. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

3. In our opinion the financial statements referred to above present fairly, in all material respects, the financial position of Rio Grande Energia S.A. and subsidiary as of December 31, 2006 and the results of their operations, the changes in stockholders’ equity and the changes in their financial position for each of the two years in the period ended December 31, 2006 in accordance with accounting practices adopted in Brazil.

/s/ PricewaterhouseCoopers
PricewaterhouseCoopers
Auditores Independentes
Porto Alegre, Brazil
April 2, 2007

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