Edgar Filing: ANADARKO PETROLEUM CORP

APC 06.30.13 10Q

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

(Mark One)

[ X ] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2013

[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

EXCHANGE ACT OF 1934

For the transition period from to

Commission File No. 1-8968

ANADARKO PETROLEUM CORPORATION

(Exact name of registrant as specified in its charter)



Delaware		76-0146568
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1201 Lake Robbins Drive, The Woodlands, Texas 77380-1046

(Address of principal executive offices)

Registrant’s telephone number, including area code (832) 636-1000

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 ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ý Accelerated filer ¨ Non-accelerated filer ¨ Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No ý

The number of shares outstanding of the Company’s common stock at June 30, 2013, is shown below:



Title of Class		Number of Shares Outstanding
Common Stock, par value $0.10 per share		502,705,709

Table of Contents

TABLE OF CONTENTS




PART I		Page

Item 1.	Financial Statements

	Consolidated Statements of Income for the Three and Six Months Ended June 30, 2013 and 2012	2

	Consolidated Statements of Comprehensive Income for the Three and Six Months Ended June 30, 2013 and 2012	3

	Consolidated Balance Sheets at June 30, 2013, and December 31, 2012	4

	Consolidated Statement of Equity for the Six Months Ended June 30, 2013	5

	Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2013 and 2012	6

	Notes to Consolidated Financial Statements	7

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	43

Item 4.	Controls and Procedures	44

PART II

Item 1.	Legal Proceedings	45

Item 1A.	Risk Factors	45

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	46

Item 6.	Exhibits	47

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ANADARKO PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
millions except per-share amounts	2013			2012			2013			2012
Revenues and Other
Natural-gas sales	$	935		$	496		$	1,742		$	1,069
Oil and condensate sales	1,995			2,222			4,372			4,466
Natural-gas liquids sales	261			282			564			624
Gathering, processing, and marketing sales	249			200			480			453
Gains (losses) on divestitures and other, net	57			22			232			57
Total	3,497			3,222			7,390			6,669
Costs and Expenses
Oil and gas operating	245			249			492			491
Oil and gas transportation and other	253			223			508			463
Exploration	178			1,121			442			1,365
Gathering, processing, and marketing	222			178			421			367
General and administrative	260			262			532			531
Depreciation, depletion, and amortization	940			1,027			1,962			1,957
Other taxes	245			326			525			703
Impairments	10			112			39			162
Algeria exceptional profits tax settlement	—			—			33			(1,804		)
Deepwater Horizon settlement and related costs	4			3			7			11
Total	2,357			3,501			4,961			4,246
Operating Income (Loss)	1,140			(279		)	2,429			2,423
Other (Income) Expense
Interest expense	172			190			336			376
(Gains) losses on derivatives, net	(656		)	(44		)	(465		)	(328		)
Other (income) expense, net	98			(519		)	92			(254		)
Total	(386		)	(373		)	(37		)	(206		)
Income (Loss) Before Income Taxes	1,526			94			2,466			2,629
Income tax expense (benefit)	567			164			1,023			516
Net Income (Loss)	959			(70		)	1,443			2,113
Net income attributable to noncontrolling interests	30			19			54			46
Net Income (Loss) Attributable to Common Stockholders	$	929		$	(89	)	$	1,389		$	2,067

Per Common Share
Net income (loss) attributable to common stockholders—basic	$	1.84		$	(0.18	)	$	2.75		$	4.11
Net income (loss) attributable to common stockholders—diluted	$	1.83		$	(0.18	)	$	2.74		$	4.10
Average Number of Common Shares Outstanding—Basic	502			500			501			499
Average Number of Common Shares Outstanding—Diluted	504			500			504			501
Dividends (per Common Share)	$	0.09		$	0.09		$	0.18		$	0.18

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

ANADARKO PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)



	Three Months Ended June 30,					Six Months Ended June 30,
millions	2013		2012			2013		2012
Net Income (Loss)	$	959	$	(70	)	$	1,443	$	2,113
Other Comprehensive Income (Loss), net of taxes
Reclassification of previously deferred derivative losses to (gains) losses on derivatives, net ⁽¹⁾	1		2			3		4
Adjustments for pension and other postretirement plans
Amortization of net actuarial (gain) loss to general and administrative expense ⁽²⁾	19		14			38		29
Amortization of net prior service (credit) cost to general and administrative expense	—		1			—		1
Total adjustments for pension and other postretirement plans	19		15			38		30
Total	20		17			41		34
Comprehensive Income (Loss)	979		(53		)	1,484		2,147
Comprehensive income attributable to noncontrolling interests	30		19			54		46
Comprehensive Income (Loss) Attributable to Common Stockholders	$	949	$	(72	)	$	1,430	$	2,101

__________________________________________________________________


⁽¹⁾	Net of income tax benefit (expense) of $(1) million for the three months ended June 30, 2013, $(1) million for the three months ended June 30, 2012, $(2) million for the six months ended June 30, 2013, and $(2) million for the six months ended June 30, 2012.


⁽²⁾	Net of income tax benefit (expense) of $(11) million for the three months ended June 30, 2013, $(9) million for the three months ended June 30, 2012, $(21) million for the six months ended June 30, 2013, and $(17) million for the six months ended June 30, 2012.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

ANADARKO PETROLEUM CORPORATION

CONSOLIDATED BALANCE SHEETS

(Unaudited)



	June 30,			December 31,
millions	2013			2012
ASSETS
Current Assets
Cash and cash equivalents	$	4,581		$	2,471
Accounts receivable (net of allowance of $5 million and $7 million)
Customers	1,302			1,473
Others	1,254			1,274
Algeria exceptional profits tax settlement	32			730
Other current assets	730			847
Total	7,899			6,795
Properties and Equipment
Cost	66,975			63,598
Less accumulated depreciation, depletion, and amortization	27,144			25,200
Net properties and equipment	39,831			38,398
Other Assets	1,893			1,716
Goodwill and Other Intangible Assets	5,677			5,680
Total Assets	$	55,300		$	52,589

LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	3,286		$	2,989
Current asset retirement obligations	285			298
Accrued expenses	1,442			707
Total	5,013			3,994
Long-term Debt	13,538			13,269
Other Long-term Liabilities
Deferred income taxes	9,378			8,759
Asset retirement obligations	1,630			1,587
Other	2,032			3,098
Total	13,040			13,444

Equity
Stockholders’ equity
Common stock, par value $0.10 per share (1.0 billion shares authorized, 521.2 million and 518.6 million shares issued)	52			51
Paid-in capital	8,481			8,230
Retained earnings	15,126			13,829
Treasury stock (18.5 million and 18.1 million shares)	(871		)	(841		)
Accumulated other comprehensive income (loss)	(599		)	(640		)
Total Stockholders’ Equity	22,189			20,629
Noncontrolling interests	1,520			1,253
Total Equity	23,709			21,882
Total Liabilities and Equity	$	55,300		$	52,589

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

ANADARKO PETROLEUM CORPORATION

CONSOLIDATED STATEMENT OF EQUITY

(Unaudited)



	Total Stockholders’ Equity
	Common Stock		Paid-in Capital		Retained Earnings			Treasury Stock			Accumulated Other Comprehensive Income (Loss)			Non- controlling Interests			Total Equity
millions
Balance at December 31, 2012	$	51	$	8,230	$	13,829		$	(841	)	$	(640	)	$	1,253		$	21,882
Net income (loss)	—		—		1,389			—			—			54			1,443
Common stock issued	1		166		—			—			—			—			167
Dividends—common	—		—		(92		)	—			—			—			(92		)
Repurchase of common stock	—		—		—			(30		)	—			—			(30		)
Subsidiary equity transactions ⁽¹⁾	—		85		—			—			—			280			365
Distributions to noncontrolling interest owners	—		—		—			—			—			(68		)	(68		)
Contributions from noncontrolling interest owners	—		—		—			—			—			1			1
Reclassification of previously deferred derivative losses to (gains) losses on derivatives, net	—		—		—			—			3			—			3
Adjustments for pension and other postretirement plans	—		—		—			—			38			—			38
Balance at June 30, 2013	$	52	$	8,481	$	15,126		$	(871	)	$	(599	)	$	1,520		$	23,709

__________________________________________________________________


⁽¹⁾	The $85 million increase to paid-in capital, together with the Company’s net income (loss) attributable to common stockholders totaled $1,474 million for the six months ended June 30, 2013.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

ANADARKO PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)



	Six Months Ended June 30,
millions	2013			2012
Cash Flows from Operating Activities
Net income (loss)	$	1,443		$	2,113
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion, and amortization	1,962			1,957
Deferred income taxes	563			143
Dry hole expense and impairments of unproved properties	263			1,187
Impairments	39			162
(Gains) losses on divestitures, net	(157		)	29
Unrealized (gains) losses on derivatives, net	(395		)	83
Other	121			120
Changes in assets and liabilities
Deepwater Horizon settlement and related costs	1			24
Algeria exceptional profits tax settlement	698			(1,691		)
Tronox-related contingent loss	—			(250		)
(Increase) decrease in accounts receivable	257			351
Increase (decrease) in accounts payable and accrued expenses	221			(486		)
Other items—net	(11		)	148
Net cash provided by (used in) operating activities	5,005			3,890
Cash Flows from Investing Activities
Additions to properties and equipment and dry hole costs	(3,531		)	(3,553		)
Acquisition of midstream business	(135		)	—
Divestitures of properties and equipment and other assets	418			258
Other—net	(341		)	(112		)
Net cash provided by (used in) investing activities	(3,589		)	(3,407		)
Cash Flows from Financing Activities
Borrowings, net of issuance costs	495			886
Repayments of debt	(245		)	(1,305		)
Increase (decrease) in outstanding checks	145			(39		)
Dividends paid	(92		)	(91		)
Repurchase of common stock	(30		)	(23		)
Issuance of common stock, including tax benefit on stock option exercises	95			38
Sale of subsidiary units	415			212
Distributions to noncontrolling interest owners	(68		)	(52		)
Contributions from noncontrolling interest owners	1			11
Net cash provided by (used in) financing activities	716			(363		)
Effect of Exchange Rate Changes on Cash	(22		)	(23		)
Net Increase (Decrease) in Cash and Cash Equivalents	2,110			97
Cash and Cash Equivalents at Beginning of Period	2,471			2,697
Cash and Cash Equivalents at End of Period	$	4,581		$	2,794

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Summary of Significant Accounting Policies

General Anadarko Petroleum Corporation is engaged in the exploration, development, production, and marketing of natural gas, crude oil, condensate, and natural gas liquids (NGLs). In addition, the Company engages in the gathering, processing, treating, and transporting of natural gas, crude oil, and NGLs. Unless the context otherwise requires, the terms “Anadarko” and “Company” refer to Anadarko Petroleum Corporation and its consolidated subsidiaries.

Basis of Presentation The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the Company’s Consolidated Balance Sheets at June 30, 2013, and December 31, 2012, the Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2013 and 2012, the Consolidated Statements of Cash Flows for the six months ended June 30, 2013 and 2012, and the Consolidated Statement of Equity for the six months ended June 30, 2013. Certain prior-period amounts have been reclassified to conform to the current-period presentation.

Use of Estimates The preparation of financial statements in accordance with accounting principles generally accepted in the United States requires management to make informed judgments and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses. Management evaluates its estimates and related assumptions regularly, including those related to the value of properties and equipment; proved reserves; goodwill; intangible assets; asset retirement obligations; litigation reserves; environmental liabilities; pension assets, liabilities, and costs; income taxes; and fair values. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.

2. Inventories

The following summarizes the major classes of inventories included in other current assets:



	June 30,		December 31,
millions	2013		2012
Crude oil	$	89	$	91
Natural gas	26		48
NGLs	49		37
Total	$	164	$	176

3. Acquisitions and Divestitures

Acquisitions In March 2013, Western Gas Partners, LP (WES), a consolidated subsidiary of the Company, acquired a 33.75% interest in gas-gathering systems located in the Marcellus shale in north-central Pennsylvania from a third party for $135 million. In June 2013, WES acquired a 25% interest in a joint venture formed to design, construct, and own two fractionators located in Mont Belvieu, Texas from a third party for $78 million.

Divestitures In the six months ended June 30, 2013, proceeds from divestitures of $418 million and net gains on divestitures of $157 million were primarily related to the Company’s divestiture of its interests in a soda ash joint venture during the first quarter of 2013.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

4. Impairments

The following summarizes impairments by segment:



	Three Months Ended June 30,				Six Months Ended June 30,
millions	2013		2012		2013		2012
Oil and gas exploration and production
Long-lived assets held for use
U.S. onshore properties	$	—	$	79	$	—	$	79
Gulf of Mexico properties	—		17		—		67
Cost-method investment	10		11		10		11
Midstream
Long-lived assets held for use	—		5		29		5
Impairments	$	10	$	112	$	39	$	162

The Company impaired its Venezuelan cost-method investment in the second quarter of 2013 and 2012 due to declines in estimated recoverable value. In addition, during the first quarter of 2013, a midstream property was impaired due to a reduction in estimated future cash flows. In 2012, U.S. onshore and midstream properties were impaired primarily due to lower natural-gas prices and a Gulf of Mexico property was impaired as a result of downward reserves revisions for a property that was near the end of its economic life.

The following summarizes the post-impairment fair value of the above-described assets, by asset category and input level within the fair-value hierarchy:



millions
2013	Level 1		Level 2		Level 3⁽¹⁾		Total
Long-lived assets held for use	$	—	$	—	$	23	$	23
Cost-method investment⁽²⁾	—		—		32		32
2012
Long-lived assets held for use	$	—	$	—	$	41	$	41
Cost-method investment⁽²⁾	—		—		34		34

__________________________________________________________________


⁽¹⁾	The income approach was used to measure fair value.


⁽²⁾	This represents the Company’s after-tax net investment.

5. Suspended Exploratory Well Costs

The Company’s suspended exploratory well costs were $2.1 billion at June 30, 2013, and December 31, 2012. Management believes projects with suspended exploratory well costs exhibit sufficient quantities of hydrocarbons to justify potential development and is actively pursuing efforts to assess whether reserves can be attributed to these projects. If additional information becomes available that raises substantial doubt as to the economic or operational viability of any of these projects, the associated costs will be expensed at that time. During the six months ended June 30, 2013, $95 million of exploratory well costs previously capitalized as suspended exploratory well costs for greater than one year at December 31, 2012, were charged to dry hole expense.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

6. Noncontrolling Interests

Western Gas Equity Partners, LP (WGP) is a consolidated subsidiary formed by Anadarko to own partnership interests in WES. At June 30, 2013, Anadarko’s ownership interest in WGP consisted of a 91.0% limited partner interest and the entire general partner interest.

WES is a limited partnership formed by Anadarko to own, operate, acquire, and develop midstream assets. In May 2013, WES issued approximately seven million common units to the public, raising net proceeds of $416 million. At June 30, 2013, WGP’s ownership interest in WES consisted of a 43.1% limited partner interest, the entire 2.0% general partner interest, and all WES incentive distribution rights. At June 30, 2013, Anadarko also owned a 0.4% limited partner interest in WES through another subsidiary.

7. Derivative Instruments

Objective and Strategy The Company uses derivative instruments to manage its exposure to cash-flow variability from commodity-price and interest-rate risks. Futures, swaps, and options are used to manage exposure to commodity-price risk inherent in the Company’s oil and natural-gas production and natural-gas processing operations (Oil and Natural-Gas Production/Processing Derivative Activities). Futures contracts and commodity-price swap agreements are used to fix the price of expected future oil and natural-gas sales at major industry trading locations, such as Henry Hub, Louisiana for natural gas and Cushing, Oklahoma or Sullom Voe, Scotland for oil. Basis swaps are periodically used to fix or float the price differential between product prices at one market location versus another. Options are used to establish a floor price, a ceiling price, or a floor and a ceiling price (collar) for expected future oil and natural-gas sales. Derivative instruments are also used to manage commodity-price risk inherent in customer price requirements and to fix margins on the future sale of natural gas and NGLs from the Company’s leased storage facilities (Marketing and Trading Derivative Activities).

Interest-rate swaps are used to fix or float interest rates on existing or anticipated indebtedness. The purpose of these instruments is to manage the Company’s existing or anticipated exposure to unfavorable interest-rate changes. The fair value of the Company’s interest-rate swap portfolio increases (decreases) when interest rates increase (decrease).

The Company does not apply hedge accounting to any of its derivative instruments. As a result, both realized and unrealized gains and losses associated with derivative instruments are recognized in earnings. Net derivative losses attributable to interest-rate derivatives previously subject to hedge accounting reside in accumulated other comprehensive income (loss) and are reclassified to earnings as the transactions to which the derivatives relate are recognized in earnings. See Note 10—Accumulated Other Comprehensive Income (Loss).

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

7. Derivative Instruments (Continued)

Oil and Natural-Gas Production/Processing Derivative Activities The natural-gas prices listed below are New York Mercantile Exchange (NYMEX) Henry Hub prices. The crude-oil prices listed below are a combination of NYMEX West Texas Intermediate (WTI) and IntercontinentalExchange, Inc. (ICE) Brent prices. The following is a summary of the Company’s derivative instruments related to its Oil and Natural-Gas Production/Processing Derivative Activities at June 30, 2013:



	2013 Settlement			2014 Settlement
Natural Gas
Two-Way Collars (thousand MMBtu/d)	600		⁽¹⁾	—
Average price per MMBtu
Ceiling sold price (call)	$	4.00		$	—
Floor purchased price (put)	$	3.18		$	—
Three-Way Collars (thousand MMBtu/d)	—		⁽²⁾	600
Average price per MMBtu
Ceiling sold price (call)	$	—		$	5.01
Floor purchased price (put)	$	—		$	3.75
Floor sold price (put)	$	—		$	2.75
Fixed-Price Contracts (thousand MMBtu/d)	1,185			600
Average price per MMBtu	$	4.00		$	4.26
Crude Oil
Three-Way Collars (MBbls/d)	26			—
Average price per barrel
Ceiling sold price (call)	$	125.15		$	—
Floor purchased price (put)	$	105.00		$	—
Floor sold price (put)	$	85.00		$	—
Fixed-Price Contracts (MBbls/d)	108			—
Average price per barrel	$	102.50		$	—

__________________________________________________________________


⁽¹⁾	The two-way collars have a contract term of April 2013 to October 2013.


⁽²⁾	The Company entered into offsetting purchased and sold natural-gas three-way collars of 450,000 MMBtu/d for 2013 settlement.

MMBtu—million British thermal units

MMBtu/d—million British thermal units per day

MBbls/d—thousand barrels per day

A two-way collar is a combination of two options: a sold call and a purchased put. The sold call establishes the maximum price that the Company will receive for the contracted commodity volumes. The purchased put establishes the minimum price that the Company will receive for the contracted volumes.

A three-way collar is a combination of three options: a sold call, a purchased put, and a sold put. The sold call establishes the maximum price that the Company will receive for the contracted commodity volumes. The purchased put establishes the minimum price that the Company will receive for the contracted volumes unless the market price for the commodity falls below the sold put strike price, at which point the minimum price equals the reference price (e.g., NYMEX) plus the excess of the purchased put strike price over the sold put strike price.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

7. Derivative Instruments (Continued)

Marketing and Trading Derivative Activities In addition to the positions in the previous table, the Company also engages in marketing and trading activities. These activities include physical product sales and related derivative transactions used to manage commodity-price risk. At June 30, 2013, the Company had fixed-price physical transactions related to natural gas totaling 8 billion cubic feet (Bcf), offset by derivative transactions totaling 8 Bcf. At December 31, 2012, the Company had fixed-price physical transactions related to natural gas totaling 10 Bcf, offset by derivative transactions totaling 10 Bcf.

Interest-Rate Derivatives Anadarko has outstanding interest-rate swap contracts as a fixed-rate payer to mitigate the interest-rate risk associated with anticipated debt issuances. The Company locked in a fixed interest rate in exchange for a floating interest rate indexed to the three-month London Interbank Offered Rate. The swap instruments include a provision that requires both the termination of the swaps and cash settlement in full at the start of the reference period.

The Company had the following outstanding interest-rate swaps at June 30, 2013:



millions except percentages		Reference Period		Weighted-Average
Notional Principal Amount		Start	End	Interest Rate
$	750	June 2014	June 2024	6.00%
$	1,100	June 2014	June 2044	5.57%
$	50	September 2016	September 2026	5.91%
$	750	September 2016	September 2046	5.86%

Effect of Derivative Instruments—Balance Sheet The following summarizes the fair value of the Company’s derivative instruments:



	Gross Derivative Assets				Gross Derivative Liabilities
millions	June 30,		December 31,		June 30,			December 31,
Balance Sheet Classification	2013		2012		2013			2012
Commodity derivatives
Other current assets	$	486	$	475	$	(212	)	$	(197	)
Other assets	86		24		(24		)	(7		)
Accrued expenses	39		6		(49		)	(14		)
Other liabilities	—		1		(4		)	(7		)
	611		506		(289		)	(225		)
Interest-rate and other derivatives
Accrued expenses ⁽¹⁾	—		—		(589		)	—
Other liabilities ⁽¹⁾	—		—		(251		)	(1,194		)
	—		—		(840		)	(1,194		)
Total derivatives	$	611	$	506	$	(1,129	)	$	(1,419	)

__________________________________________________________________


⁽¹⁾	Interest-rate swaps with June 2014 maturity dates were reclassified from other liabilities to accrued expenses during the second quarter of 2013.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

7. Derivative Instruments (Continued)

Effect of Derivative Instruments—Statement of Income The following summarizes realized and unrealized gains and losses related to derivative instruments:



millions	Three Months Ended June 30, 2013									Six Months Ended June 30, 2013
Classification of (Gain) Loss Recognized	Realized			Unrealized			Total			Realized			Unrealized			Total
Commodity derivatives
Gathering, processing, and marketing sales ⁽¹⁾	$	3		$	(6	)	$	(3	)	$	7		$	(2	)	$	5
(Gains) losses on derivatives, net	(21		)	(373		)	(394		)	(72		)	(39		)	(111		)
Interest-rate and other derivatives
(Gains) losses on derivatives, net	—			(262		)	(262		)	—			(354		)	(354		)
Total (gains) losses on derivatives, net	$	(18	)	$	(641	)	$	(659	)	$	(65	)	$	(395	)	$	(460	)

	Three Months Ended June 30, 2012									Six Months Ended June 30, 2012
Classification of (Gain) Loss Recognized	Realized			Unrealized			Total			Realized			Unrealized			Total
Commodity derivatives
Gathering, processing, and marketing sales ⁽¹⁾	$	(1	)	$	8		$	7		$	(3	)	$	13		$	10
(Gains) losses on derivatives, net	(263		)	(157		)	(420		)	(400		)	(68		)	(468		)
Interest-rate and other derivatives
(Gains) losses on derivatives, net	2			374			376			2			138			140
Total (gains) losses on derivatives, net	$	(262	)	$	225		$	(37	)	$	(401	)	$	83		$	(318	)

__________________________________________________________________


⁽¹⁾	Represents the effect of marketing and trading derivative activities.

Credit-Risk Considerations The financial integrity of exchange-traded contracts, which are subject to nominal credit risk, is assured by NYMEX or ICE through systems of financial safeguards and transaction guarantees. Over-the-counter traded swaps, options, and futures contracts expose the Company to counterparty credit risk. The Company monitors the creditworthiness of its counterparties, establishes credit limits according to the Company’s credit policies and guidelines, and assesses the impact on fair value of its counterparties’ creditworthiness. The Company has the ability to require cash collateral or letters of credit to mitigate its credit-risk exposure. The Company has netting agreements with financial institutions that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities, and routinely exercises its contractual right to offset realized gains against realized losses when settling with derivative counterparties.

In addition, the Company has setoff agreements with certain financial institutions that may be exercised in the event of default and provide for contract termination and net settlement across derivative types. At June 30, 2013, $437 million of the Company’s $1.1 billion gross derivative liability balance, and at December 31, 2012, $339 million of the Company’s $1.4 billion gross derivative liability balance, would have been eligible for setoff against the Company’s gross derivative asset balance in the event of default. Other than in the event of default, the Company does not net settle across derivative types.

Some of the Company’s derivative instruments are subject to provisions that can require full or partial collateralization or immediate settlement of the Company’s obligations if certain credit-risk-related provisions are triggered. However, most of the Company’s derivative counterparties maintain secured positions with respect to the Company’s derivative liabilities under the Company’s $5.0 billion senior secured revolving credit facility ($5.0 billion Facility), the available capacity of which is sufficient to secure potential obligations to such counterparties.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

7. Derivative Instruments (Continued)

Unsecured derivative obligations may require immediate settlement or full collateralization if certain credit-risk-related provisions are triggered, such as the Company’s credit rating from major credit rating agencies declining to a level below investment grade. The aggregate fair value of derivative instruments with credit-risk-related contingent features for which a net liability position existed was $62 million (net of collateral) at June 30, 2013, and $94 million (net of collateral) at December 31, 2012. The current portion of these amounts was included in accrued expenses and the long-term portion of these amounts was included in other long-term liabilities—other on the Company’s Consolidated Balance Sheets.

Fair Value Fair value of futures contracts is based on quoted prices in active markets for identical assets or liabilities, which represent Level 1 inputs. Valuations of physical-delivery purchase and sale agreements, over-the-counter financial swaps, and commodity option collars are based on similar transactions observable in active markets and industry-standard models that primarily rely on market-observable inputs. Inputs used to estimate the fair value of swaps and options include market-price curves; contract terms and prices; credit-risk adjustments; and, for Black-Scholes option valuations, implied market volatility and discount factors. Inputs used to estimate fair value in industry-standard models are categorized as Level 2 inputs because substantially all assumptions and inputs are observable in active markets throughout the full term of the instruments.

The following summarizes the fair value of the Company’s derivative assets and liabilities, by input level within the fair-value hierarchy:



millions
June 30, 2013	Level 1			Level 2			Level 3		Netting ⁽¹⁾			Collateral			Total
Assets
Commodity derivatives
Financial institutions	$	3		$	550		$	—	$	(268	)	$	(1	)	$	284
Other counterparties	—			58			—		(7		)	—			51
Total derivative assets	$	3		$	608		$	—	$	(275	)	$	(1	)	$	335
Liabilities
Commodity derivatives
Financial institutions	$	(3	)	$	(269	)	$	—	$	268		$	2		$	(2	)
Other counterparties	—			(17		)	—		7			—			(10		)
Interest-rate and other derivatives	—			(840		)	—		—			—			(840		)
Total derivative liabilities	$	(3	)	$	(1,126	)	$	—	$	275		$	2		$	(852	)


December 31, 2012
Assets
Commodity derivatives
Financial institutions	$	6		$	453		$	—	$	(206	)	$	—		$	253
Other counterparties	—			47			—		(5		)	—			42
Total derivative assets	$	6		$	500		$	—	$	(211	)	$	—		$	295
Liabilities
Commodity derivatives
Financial institutions	$	(6	)	$	(202	)	$	—	$	206		$	1		$	(1	)
Other counterparties	—			(17		)	—		5			—			(12		)
Interest-rate and other derivatives	—			(1,194		)	—		—			—			(1,194		)
Total derivative liabilities	$	(6	)	$	(1,413	)	$	—	$	211		$	1		$	(1,207	)

__________________________________________________________________


⁽¹⁾	Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

8. Debt and Interest Expense

Debt The Company’s outstanding debt is senior unsecured, except for borrowings, if any, under the $5.0 billion Facility. The following summarizes the Company’s outstanding debt:



	June 30,			December 31,
millions	2013			2012
Total debt at face value	$	15,202		$	14,952
Net unamortized discounts and premiums ⁽¹⁾	(1,664		)	(1,683		)
Total long-term debt	$	13,538		$	13,269

__________________________________________________________________


⁽¹⁾	Unamortized discounts and premiums are amortized over the term of the related debt.

Anadarko’s $500 million aggregate principal amount of 7.625% Senior Notes due March 2014, $275 million aggregate principal amount of 5.750% Senior Notes due June 2014, and Zero-Coupon Senior Notes due 2036, which can be put to the Company in October 2013 for the then-accreted value, are classified as long-term debt on the Company’s Consolidated Balance Sheets, as the Company has the ability and intent to refinance these obligations using long-term debt.

Fair Value The Company uses a market approach to determine fair value of its fixed-rate debt using observable market data, which results in a Level 2 fair-value measurement. The carrying amount of floating-rate debt approximates fair value as the interest rates are variable and reflective of market rates. The estimated fair value of the Company’s total borrowings was $15.6 billion at June 30, 2013, and $16.2 billion at December 31, 2012.

Debt Activity The following summarizes the Company’s debt activity during the six months ended June 30, 2013:



	Carrying
millions	Value			Description
Balance at December 31, 2012	$	13,269
Borrowings	385			WES revolving credit facility
Other, net	9			Amortization of debt discounts and premiums
Balance at March 31, 2013	$	13,663
Borrowings	110			WES revolving credit facility
Repayments	(245		)	WES revolving credit facility
Other, net	10			Amortization of debt discounts and premiums
Balance at June 30, 2013	$	13,538

WES Borrowings At June 30, 2013, WES was in compliance with all covenants contained in its five-year, $800 million senior unsecured revolving credit facility maturing in March 2016 (RCF), had outstanding borrowings under the RCF of $250 million at an interest rate of 1.70%, and had available borrowing capacity of $537 million ($800 million maximum capacity, less $250 million of outstanding borrowings and $13 million of outstanding letters of credit).

Interest Expense The following summarizes interest expense:



	Three Months Ended June 30,						Six Months Ended June 30,
millions	2013			2012			2013			2012
Current debt, long-term debt, and other	$	238		$	236		$	470		$	486
Capitalized interest	(66		)	(46		)	(134		)	(110		)
Interest expense	$	172		$	190		$	336		$	376

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

9. Stockholders' Equity

The reconciliation between basic and diluted earnings per share attributable to common stockholders is as follows:



	Three Months Ended June 30,					Six Months Ended June 30,
millions except per-share amounts	2013		2012			2013		2012
Net income (loss)
Net income (loss) attributable to common stockholders	$	929	$	(89	)	$	1,389	$	2,067
Less distributions on participating securities	1		—			1		1
Less undistributed income allocated to participating securities	5		—			8		12
Basic	$	923	$	(89	)	$	1,380	$	2,054
Diluted	$	923	$	(89	)	$	1,380	$	2,054
Shares
Average number of common shares outstanding—basic	502		500			501		499
Dilutive effect of stock options	2		—			3		2
Average number of common shares outstanding—diluted	504		500			504		501
Excluded ⁽¹⁾	5		12			4		5
Net income (loss) per common share
Basic	$	1.84	$	(0.18	)	$	2.75	$	4.11
Diluted	$	1.83	$	(0.18	)	$	2.74	$	4.10

Dividends per common share	$	0.09	$	0.09		$	0.18	$	0.18

__________________________________________________________________


⁽¹⁾	Inclusion of certain shares would have had an anti-dilutive effect.

10. Accumulated Other Comprehensive Income (Loss)

The following summarizes the after-tax changes in the balances of each component of accumulated other comprehensive income (loss):



	Interest-rate
	Derivatives			Pension and
	Previously			Other
	Subject to Hedge			Postretirement
millions	Accounting			Plans			Total
Balance at December 31, 2012	$	(61	)	$	(579	)	$	(640	)
Reclassifications from accumulated other comprehensive income (loss)	3			38			41
Balance at June 30, 2013	$	(58	)	$	(541	)	$	(599	)

11. Commitments

In June 2013, the Company entered into a three-year operating lease agreement for a deepwater drillship expected to be delivered mid-2014. The lease obligation totals $464 million, with aggregate future annual minimum lease payments of $104 million in 2014, $154 million in 2015, $155 million in 2016, and $51 million in 2017.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Contingencies

General The Company is a defendant in a number of lawsuits and is involved in governmental proceedings and regulatory controls arising in the ordinary course of business, including, but not limited to, personal injury claims; title disputes; tax disputes; royalty claims; contract claims; contamination claims relating to oil and gas production, transportation, and processing; and environmental claims, including claims involving assets owned by acquired companies. Anadarko is also subject to various environmental-remediation and reclamation obligations arising from federal, state, and local laws and regulations. While the ultimate outcome and impact on the Company cannot be predicted with certainty, after consideration of recorded expense and liability accruals, management believes that the resolution of pending proceedings will not have a material adverse effect on the Company’s consolidated financial position, results of operations, or cash flows.

The following is a discussion of the material developments with respect to the contingencies previously reported in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, and material matters that have arisen since the filing of such report.

Deepwater Horizon Events In April 2010, the Macondo well in the Gulf of Mexico blew out and an explosion occurred on the Deepwater Horizon drilling rig. The well was operated by BP Exploration and Production Inc. (BP) and Anadarko held a 25% nonoperated interest. In October 2011, the Company and BP entered into a settlement agreement relating to the Deepwater Horizon events (Settlement Agreement). Pursuant to the Settlement Agreement, the Company is fully indemnified by BP against claims and damages arising under the Oil Pollution Act of 1990 (OPA), claims for natural resource damages (NRD) and assessment costs, and other potential damages. This indemnification is guaranteed by BP Corporation North America Inc. (BPCNA) and, in the event that the net worth of BPCNA declines below an agreed-upon amount, BP p.l.c. has agreed to become the sole guarantor. Under the Settlement Agreement, BP does not indemnify the Company against fines and penalties, punitive damages, shareholder derivative or securities laws claims, or certain other claims. The Company has not recorded a liability for any costs that are subject to indemnification by BP. For additional disclosure of the Deepwater Horizon events, the Company’s Settlement Agreement with BP, environmental claims under OPA, NRD claims, potential penalties and fines, and civil litigation, see Note 17—Contingencies—Deepwater Horizon Events in the Notes to the Consolidated Financial Statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

Penalties and Fines In December 2010, the U.S. Department of Justice (DOJ), on behalf of the United States, filed a civil lawsuit in the U.S. District Court in New Orleans, Louisiana (Louisiana District Court) against several parties, including Anadarko, seeking an assessment of civil penalties under the Clean Water Act (CWA) in an amount to be determined by the Louisiana District Court. In February 2012, the Louisiana District Court entered a declaratory judgment that, as a partial owner of the Macondo well, Anadarko is liable for civil penalties under Section 311 of the CWA. The declaratory judgment addresses liability only, and does not address the amount of any civil penalty. The assessment of a civil penalty against Anadarko has been reserved until a later proceeding to be scheduled by the Louisiana District Court. In August 2012, Anadarko filed a notice of appeal in the U.S. Court of Appeals for the Fifth Circuit concerning that portion of the February 2012 declaratory judgment finding Anadarko liable for civil penalties under the CWA. The appeal is pending.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Contingencies (Continued)

As discussed below, numerous Deepwater Horizon event-related civil lawsuits have been filed against BP and other parties, including the Company. Certain state and local governments have appealed, or have provided indication of a likely appeal of, the Louisiana District Court’s decision that only federal law, and not state law, applies to Deepwater Horizon event-related claims. If any such appeal is successful, state and/or local laws and regulations could become sources of penalties or fines against the Company.

Applicable accounting guidance requires the Company to accrue a liability if it is probable that a liability is incurred and the amount of the liability can be reasonably estimated. The Louisiana District Court’s declaratory judgment in February 2012 satisfies the requirement that a loss, arising from the future assessment of a civil penalty against Anadarko, is probable. Notwithstanding the declaratory judgment, the Company currently cannot estimate the amount of any potential civil penalty. The CWA sets forth subjective criteria, including degree of fault and history of prior violations, which significantly influence the magnitude of CWA penalty assessments. As a result of the subjective nature of CWA penalty assessments, the Company currently cannot estimate the amount of any such penalty nor determine a range of potential loss. Furthermore, neither the February 2012 settlement of Deepwater Horizon-related civil penalties (including those under the CWA) by the other nonoperating partner with the United States and five affected Gulf states (Texas, Louisiana, Mississippi, Alabama, and Florida) nor the January 2013 settlement of CWA civil and criminal penalties by the drilling contractor with the United States affects the Company’s current conclusion regarding its ability to estimate potential fines and penalties. The Company lacks insight into those settlements, retains legal counsel separate from the other parties, and was not involved in any manner with respect to those settlements. Events or factors that could assist the Company in estimating the amount of any potential civil penalty or a range of potential loss related to such penalties include (i) an assessment by the DOJ, (ii) a ruling by a court of competent jurisdiction, or (iii) the initiation of substantive settlement negotiations between the Company and the DOJ.

Given the Company’s lack of direct operational involvement in the event, as confirmed by the Louisiana District Court, and the subjective criteria of the CWA, the Company believes that its exposure to CWA penalties will not materially impact the Company’s consolidated financial position, results of operations, or cash flows.

Civil Litigation Damage Claims Numerous Deepwater Horizon event-related civil lawsuits have been filed against BP and other parties, including the Company. This litigation has been consolidated into a federal Multidistrict Litigation (MDL) action pending before Judge Carl Barbier in the Louisiana District Court. In March 2012, BP and the Plaintiffs’ Steering Committee entered into a tentative settlement agreement to resolve the substantial majority of economic loss and medical claims stemming from the Deepwater Horizon events, which the Louisiana District Court approved in orders issued in December 2012 and January 2013. Only OPA claims seeking economic loss damages against the Company remain. In addition, certain state and local governments have appealed, or have provided indication of a likely appeal of, the MDL court’s decision that only federal law, and not state law, applies to Deepwater Horizon event-related claims. The Company, pursuant to the Settlement Agreement, is fully indemnified by BP against losses arising as a result of claims for damages, irrespective of whether such claims are based on federal (including OPA) or state law.

The first phase of the trial in the proceeding filed in the MDL by Transocean Ltd. (Transocean) under the Limitation of Liability Act commenced in February 2013 (Phase I). In April 2013, the evidence closed and all parties rested. Findings of fact, post-trial briefs, and responsive briefs were submitted in July 2013. BP, BP p.l.c., the United States, state and local governments, Halliburton Energy Services, Inc. (Halliburton), and Transocean participated in Phase I of the trial. Anadarko was excused from participation in Phase I of the trial. The issues tried in Phase I include the cause of the blow-out and all related events leading up to April 22, 2010, the date the Deepwater Horizon sank, as well as allocation of fault. The allocation of fault remains in the Phase I trial because Halliburton and Transocean have not settled with any of the parties and each wishes to prove to the court that their respective company was not at fault. The second phase of trial is expected to start in September 2013 (Phase II). The issues to be tried in Phase II are expected to include spill-source control and quantification of the spill for the period from April 22, 2010, until the well was capped. The Company, BP, BP p.l.c., the United States, state and local governments, Halliburton, and Transocean will participate in Phase II of the trial.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Contingencies (Continued)

Two separate class action complaints were filed in June and August 2010, in the U.S. District Court for the Southern District of New York (New York District Court) on behalf of purported purchasers of the Company’s stock between June 9, 2009, and June 12, 2010, against Anadarko and certain of its officers. The complaints allege causes of action arising pursuant to the Securities Exchange Act of 1934 for purported misstatements and omissions regarding, among other things, the Company’s liability related to the Deepwater Horizon events. In March 2012, the New York District Court granted the Lead Plaintiff’s motion to transfer venue to the U.S. District Court for the Southern District of Texas - Houston Division (Texas District Court). In May 2012, the Texas District Court granted the defendants’ motion to transfer the consolidated action within the district to Judge Keith P. Ellison. In July 2012, the plaintiffs filed their First Amended Consolidated Class Action Complaint. The defendants filed a renewed motion to dismiss in the Texas District Court in September 2012. In July 2013, the Texas District Court dismissed the claims relating to all but one of the alleged misstatements asserted in the plaintiffs’ complaint. The Texas District Court has given the plaintiffs 30 days to seek leave to amend the complaint to attempt to rehabilitate the claims that were dismissed.

In September 2010, a purported shareholder made a demand on the Company’s Board of Directors (the Board) to investigate allegations of breaches of duty by members of management related to the Deepwater Horizon events. The Board received a supplemental demand letter from the shareholder in March 2012. The Board considered each of the demand letters in January 2011 and April 2012 and determined that it would not be in the best interest of the Company to pursue the issues alleged in the demand letters. In May 2013, a shareholder derivative petition was filed in the 215^th District Court of Harris County, Texas by the shareholder against Anadarko (as a nominal defendant) and certain current and former directors and officers. The petition alleges breach of fiduciary duties, unjust enrichment, abuse of control, and gross mismanagement in connection with the Deepwater Horizon events. The plaintiff seeks an unspecified amount of damages, certain changes to the Company’s governance and internal procedures, disgorgement of profits, and reimbursement of litigation fees and costs.

Given the various stages of these matters, the Company currently cannot assess the probability of losses, or reasonably estimate a range of any potential losses, related to ongoing proceedings. The Company intends to vigorously defend itself, its officers, and its directors in each of these matters, and will avail itself of the indemnities provided by BP against civil damages.

Remaining Liability Outlook It is reasonably possible that the Company may recognize additional Deepwater Horizon event-related liabilities for potential fines and penalties, shareholder claims, and certain other claims not covered by the indemnification provisions of the Settlement Agreement; however, the Company does not believe that any potential liability attributable to the foregoing items, individually or in the aggregate, will have a material impact on the Company’s consolidated financial position, results of operations, or cash flows. This assessment takes into account certain qualitative factors, including the subjective and fault-based nature of CWA penalties, the Company’s indemnification by BP against certain damage claims as discussed above, BP’s creditworthiness, the merits of the shareholder claims, and directors’ and officers’ insurance coverage related to outstanding shareholder claims.

The Company will continue to monitor the MDL and other legal proceedings discussed above as well as federal investigations related to the Deepwater Horizon events. The Company cannot predict the nature of evidence that may be discovered during the course of legal proceedings or the timing of completion of any legal proceedings.

Although the Company is fully indemnified by BP against OPA damage claims, NRD claims and assessment costs, and certain other potential liabilities, the Company may be required to recognize a liability for these amounts in advance of or in connection with recognizing a receivable from BP for the related indemnity payment. In all circumstances, however, the Company expects that any additional indemnified liability that may be recognized by the Company will be subsequently recovered from BP itself or through the guarantees of BPCNA or BP p.l.c.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

12. Contingencies (Continued)

Tronox Litigation In January 2009, Tronox Incorporated (Tronox), a former subsidiary of Kerr-McGee Corporation (Kerr-McGee), which is a current subsidiary of Anadarko, and certain of Tronox’s subsidiaries filed voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Southern District of New York. Subsequently, in May 2009, Tronox and certain of its affiliates filed a lawsuit against Anadarko and Kerr-McGee asserting a number of claims, including claims for actual and constructive fraudulent conveyance (Adversary Proceeding). Tronox alleges, among other things, that it was insolvent or undercapitalized at the time it was spun off from Kerr-McGee and seeks, among other things, to recover damages, including interest, in excess of $18.9 billion from Kerr-McGee and Anadarko, as well as litigation fees and costs. In accordance with Tronox’s Plan of Reorganization, the Adversary Proceeding is being pursued by the Anadarko Litigation Trust. Pursuant to the Anadarko Litigation Trust Agreement, the Anadarko Litigation Trust was “deemed substituted” for Tronox in the Adversary Proceeding as the party in such litigation. For purposes of this Form 10-Q, references to “Tronox” after February 2011 refer to the Anadarko Litigation Trust. For additional disclosure related to the Tronox Litigation, see Note 17—Contingencies—Tronox Litigation in the Notes to the Consolidated Financial Statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

The U.S. government was granted authority to intervene in the Adversary Proceeding, and in May 2009 asserted separate claims against Anadarko and Kerr-McGee under the Federal Debt Collection Procedures Act (FDCPA Complaint). Anadarko and Kerr-McGee moved to dismiss the claims of the U.S. government, but that motion has been stayed by the Bankruptcy Court. In April 2012, Anadarko and Kerr-McGee filed an answer to the FDCPA Complaint.

In February 2012, the Company filed a motion for partial summary judgment seeking dismissal of several claims, including all actual and constructive fraudulent transfer claims protected by Section 546(e) of the Bankruptcy Code. The court has not yet ruled on that issue. Trial began in May 2012 and in September 2012, the evidence closed and both sides rested. In November 2012, the parties filed post-trial briefs and closing arguments were presented in December 2012. The parties filed final post-trial briefs in January 2013. The matter is pending before the court.

The Company remains confident in the merits of its position and does not believe a loss resulting from litigating the Adversary Proceeding is probable. Accounting guidance requires that contingent losses be probable in nature for loss recognition to be appropriate. Accordingly, the Company’s Consolidated Balance Sheet at June 30, 2013, does not include a loss-contingency liability related to the litigation of the Adversary Proceeding.

Although the Company does not consider a loss related to the litigation of the Adversary Proceeding to be probable, it is reasonably possible that the Company could incur a loss as a result of litigating this matter. Despite the plaintiffs’ damage claims in excess of $18.9 billion, the Company currently believes a reasonable range of potential loss is zero to $1.4 billion. The low end of the Company’s estimated range of potential loss is based on the Company’s current belief that it will more likely than not prevail in defending against the claims asserted in the Adversary Proceeding. The high end of the Company’s estimated range of potential loss represents the amount of consideration received by Kerr-McGee at the time of the Tronox spin-off, approximately $985 million, plus interest thereon.

The Company’s estimated range of potential loss is based on the Company’s opinion regarding the current status of and likelihood of final resolution through litigation and could change as a result of developments in the Adversary Proceeding, or if the likelihood of settlement ceases to be remote. The Company’s ultimate financial obligation resulting from resolution of the Adversary Proceeding could vary, perhaps materially, from the Company’s above-stated estimated range of potential loss.

Other During the second quarter of 2013, the Company recognized a pretax loss of $141 million, reported in other (income) expense, net in the Consolidated Statement of Income, related to the cost to decommission wells and production facilities previously sold to a third party. In June 2013, as a result of a Chapter 11 bankruptcy declaration by the third party, the U.S. Department of the Interior ordered Anadarko to perform the decommissioning of the facility and related wells. These wells and production facilities are no longer owned by the Company nor related to its current operations. Anadarko expects to complete decommissioning of the production facilities in 2014 and the wells in 2015. Decommissioning obligations of $56 million were included in accrued expenses and $85 million were included in other long-term liabilities in the Consolidated Balance Sheet at June 30, 2013. Actual costs may vary from this estimate; however, the Company does not believe that such variation will materially impact its consolidated financial position, results of operations, or cash flows.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

13. Income Taxes

The following summarizes income tax expense (benefit) and effective tax rates:



	Three Months Ended June 30,						Six Months Ended June 30,
millions except percentages	2013			2012			2013			2012
Income tax expense (benefit)	$	567		$	164		$	1,023		$	516
Effective tax rate	37		%	174		%	41		%	20		%

The increase from the 35% U.S. federal statutory rate for the three and six months ended June 30, 2013, and the three months ended June 30, 2012, was primarily attributable to the tax impact from foreign operations and Algerian exceptional profits taxes.

The decrease from the 35% U.S. federal statutory rate for the six months ended June 30, 2012, was primarily attributable to the non-taxable resolution of the Algeria exceptional profits tax dispute. This amount was partially offset by the tax impact from foreign operations and Algerian exceptional profits taxes.

14. Supplemental Cash Flow Information

The following summarizes cash paid (received) for interest (net of amounts capitalized) and income taxes, as well as non-cash investing transactions:



	Six Months Ended June 30,
millions	2013		2012
Cash paid (received)
Interest	$	313	$	354
Income taxes	$	103	$	(40	)
Non-cash investing activities
Fair value of properties and equipment received in non-cash exchange transactions	$	13	$	31

15. Segment Information

Anadarko’s business segments are separately managed due to distinct operational differences and unique technology, distribution, and marketing requirements. The Company’s three reporting segments are oil and gas exploration and production, midstream, and marketing. The oil and gas exploration and production segment explores for and produces natural gas, crude oil, condensate, and NGLs. The midstream segment engages in gathering, processing, treating, and transporting Anadarko and third-party oil, natural-gas, and NGLs production. The midstream reporting segment consists of two operating segments, WES and other midstream, which are aggregated into one reporting segment due to similar financial and operating characteristics. The marketing segment sells much of Anadarko’s production, as well as third-party purchased volumes.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

15. Segment Information (Continued)

To assess the performance of Anadarko’s operating segments, the chief operating decision maker analyzes Adjusted EBITDAX. The Company defines Adjusted EBITDAX as income (loss) before income taxes; exploration expense; depreciation, depletion, and amortization (DD&A); impairments; interest expense; unrealized (gains) losses on derivatives, net; realized (gains) losses on interest-rate and other derivatives, net; and certain items not related to the Company’s normal operations, less net income attributable to noncontrolling interests. During the periods presented, these items included Deepwater Horizon settlement and related costs, Algeria exceptional profits tax settlement, Tronox-related contingent loss, and certain other nonoperating items included in other (income) expense, net. The Company’s definition of Adjusted EBITDAX excludes exploration expense, as it is not an indicator of operating efficiency for a given reporting period. However, exploration expense is monitored by management as part of costs incurred in exploration and development activities. Similarly, DD&A and impairments are excluded from Adjusted EBITDAX as a measure of segment operating performance because capital expenditures are evaluated at the time capital costs are incurred. Adjusted EBITDAX also excludes interest expense to allow for assessment of segment operating results without regard to Anadarko’s financing methods or capital structure. Finally, unrealized (gains) losses on derivatives, net and realized (gains) losses on interest-rate and other derivatives, net are excluded from Adjusted EBITDAX because these (gains) losses are not considered a measure of asset operating performance. Management believes that the presentation of Adjusted EBITDAX provides information useful in assessing the Company’s financial condition and results of operations and that Adjusted EBITDAX is a widely accepted financial indicator of a company’s ability to incur and service debt, fund capital expenditures, and make distributions to stockholders.

Adjusted EBITDAX, as defined by Anadarko, may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with net income (loss) attributable to common stockholders and other performance measures, such as operating income or cash flows from operating activities. Below is a reconciliation of consolidated Adjusted EBITDAX to income (loss) before income taxes:



	Three Months Ended June 30,						Six Months Ended June 30,
millions	2013			2012			2013			2012
Income (loss) before income taxes	$	1,526		$	94		$	2,466		$	2,629
Exploration expense	178			1,121			442			1,365
DD&A	940			1,027			1,962			1,957
Impairments	10			112			39			162
Interest expense	172			190			336			376
Unrealized (gains) losses on derivatives, net	(641		)	225			(395		)	83
Realized (gains) losses on interest-rate and other derivatives, net	—			2			—			2
Deepwater Horizon settlement and related costs	4			3			7			11
Algeria exceptional profits tax settlement	—			—			33			(1,804		)
Tronox-related contingent loss	—			(525		)	—			(250		)
Certain other nonoperating items	85			—			85			—
Less net income attributable to noncontrolling interests	30			19			54			46
Consolidated Adjusted EBITDAX	$	2,244		$	2,230		$	4,921		$	4,485

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

15. Segment Information (Continued)

Information presented below as “Other and Intersegment Eliminations” includes results from hard-minerals royalty arrangements and corporate, financing, and certain hedging activities. The following summarizes selected financial information for Anadarko’s reporting segments:



	Oil and Gas									Other and
	Exploration									Intersegment
millions	& Production			Midstream			Marketing			Eliminations			Total
Three Months Ended June 30, 2013
Sales revenues	$	1,587		$	88		$	1,765		$	—		$	3,440
Intersegment revenues	1,526			265			(1,639		)	(152		)	—
Gains (losses) on divestitures and other, net	1			—			—			56			57
Total revenues and other	3,114			353			126			(96		)	3,497
Operating costs and expenses ⁽¹⁾	845			209			164			7			1,225
Realized (gains) losses on commodity derivatives, net	—			—			—			(21		)	(21		)
Other (income) expense, net ⁽²⁾	—			—			—			13			13
Net income attributable to noncontrolling interests	—			30			—			—			30
Total expenses and other	845			239			164			(1		)	1,247
Unrealized (gains) losses on derivatives, net included in marketing revenue	—			—			(6		)	—			(6		)
Adjusted EBITDAX	$	2,269		$	114		$	(44	)	$	(95	)	$	2,244

Three Months Ended June 30, 2012
Sales revenues	$	1,888		$	81		$	1,231		$	—		$	3,200
Intersegment revenues	1,035			220			(1,124		)	(131		)	—
Gains (losses) on divestitures and other, net	(12		)	(1		)	—			35			22
Total revenues and other	2,911			300			107			(96		)	3,222
Operating costs and expenses ⁽¹⁾	873			174			158			33			1,238
Realized (gains) losses on commodity derivatives, net	—			—			—			(263		)	(263		)
Other (income) expense, net ⁽²⁾	—			—			—			6			6
Net income attributable to noncontrolling interests	—			19			—			—			19
Total expenses and other	873			193			158			(224		)	1,000
Unrealized (gains) losses on derivatives, net included in marketing revenue	—			—			8			—			8
Adjusted EBITDAX	$	2,038		$	107		$	(43	)	$	128		$	2,230

__________________________________________________________________


⁽¹⁾	Operating costs and expenses excludes exploration expense, DD&A, impairments, Deepwater Horizon settlement and related costs, and Algeria exceptional profits tax settlement since these expenses are excluded from Adjusted EBITDAX.


⁽²⁾	Other (income) expense, net excludes Tronox-related contingent loss and certain other nonoperating items since these expenses are excluded from Adjusted EBITDAX.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

15. Segment Information (Continued)



	Oil and Gas									Other and
	Exploration									Intersegment
millions	& Production			Midstream			Marketing			Eliminations			Total
Six Months Ended June 30, 2013
Sales revenues	$	3,128		$	172		$	3,858		$	—		$	7,158
Intersegment revenues	3,388			518			(3,605		)	(301		)	—
Gains (losses) on divestitures and other, net	5			—			—			227			232
Total revenues and other	6,521			690			253			(74		)	7,390
Operating costs and expenses ⁽¹⁾	1,726			397			328			27			2,478
Realized (gains) losses on commodity derivatives, net	—			—			—			(72		)	(72		)
Other (income) expense, net ⁽²⁾	—			—			—			7			7
Net income attributable to noncontrolling interests	—			54			—			—			54
Total expenses and other	1,726			451			328			(38		)	2,467
Unrealized (gains) losses on derivatives, net included in marketing revenue	—			—			(2		)	—			(2		)
Adjusted EBITDAX	$	4,795		$	239		$	(77	)	$	(36	)	$	4,921

Six Months Ended June 30, 2012
Sales revenues	$	3,787		$	168		$	2,657		$	—		$	6,612
Intersegment revenues	2,209			469			(2,419		)	(259		)	—
Gains (losses) on divestitures and other, net	(29		)	(2		)	—			88			57
Total revenues and other	5,967			635			238			(171		)	6,669
Operating costs and expenses ⁽¹⁾	1,799			363			312			81			2,555
Realized (gains) losses on commodity derivatives, net	—			—			—			(400		)	(400		)
Other (income) expense, net ⁽²⁾	—			—			—			(4		)	(4		)
Net income attributable to noncontrolling interests	—			46			—			—			46
Total expenses and other	1,799			409			312			(323		)	2,197
Unrealized (gains) losses on derivatives, net included in marketing revenue	—			—			13			—			13
Adjusted EBITDAX	$	4,168		$	226		$	(61	)	$	152		$	4,485

__________________________________________________________________


⁽¹⁾	Operating costs and expenses excludes exploration expense, DD&A, impairments, Deepwater Horizon settlement and related costs, and Algeria exceptional profits tax settlement since these expenses are excluded from Adjusted EBITDAX.


⁽²⁾	Other (income) expense, net excludes Tronox-related contingent loss and certain other nonoperating items since these expenses are excluded from Adjusted EBITDAX.

Table of Contents

ANADARKO PETROLEUM CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

16. Pension Plans and Other Postretirement Benefits

The Company has contributory and non-contributory defined-benefit pension plans, which include both qualified and supplemental plans. The Company also provides certain health care and life insurance benefits for certain retired employees. Retiree health care benefits are funded by contributions from the retiree, and in certain circumstances, contributions from the Company. The Company’s retiree life insurance plan is noncontributory.

The following summarizes the Company’s pension and other postretirement benefit cost:



	Pension Benefits						Other Benefits
millions	2013			2012			2013		2012
Three Months Ended June 30
Service cost	$	22		$	19		$	3	$	3
Interest cost	19			22			3		4
Expected return on plan assets	(23		)	(22		)	—		—
Amortization of net actuarial loss (gain)	30			23			—		—
Amortization of net prior service cost (credit)	—			—			—		1
Net periodic benefit cost	$	48		$	42		$	6	$	8

Six Months Ended June 30
Service cost	$	43		$	38		$	5	$	5
Interest cost	39			43			7		8
Expected return on plan assets	(46		)	(45		)	—		—
Amortization of net actuarial loss (gain)	59			46			—		—
Amortization of net prior service cost (credit)	—			—			—		1
Net periodic benefit cost	$	95		$	82		$	12	$	14

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Unless the context otherwise requires, the terms “Anadarko” and “Company” refer to Anadarko Petroleum Corporation and its consolidated subsidiaries. The Company has made in this report, and may from time to time make in other public filings, press releases, and management discussions, forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 concerning the Company’s operations, economic performance, and financial condition. These forward-looking statements include information concerning future production and reserves, schedules, plans, timing of development, contributions from oil and gas properties, marketing and midstream activities, and also include those statements preceded by, followed by, or that otherwise include the words “may,” “could,” “believes,” “expects,” “anticipates,” “intends,” “estimates,” “projects,” “target,” “goal,” “plans,” “objective,” “should,” “would,” “will,” “potential,” “continue,” “forecast,” “future,” “likely,” “outlook,” or similar expressions or variations on such expressions. For such statements, the Company claims the protection of the safe harbor for forward-looking statements contained in the Private Securities Litigation Reform Act of 1995. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will be realized. Anadarko undertakes no obligation to publicly update or revise any forward-looking statements whether as a result of new information, future events, or otherwise.

These forward-looking statements involve risk and uncertainties. Important factors that could cause actual results to differ materially from the Company’s expectations include, but are not limited to, the following risks and uncertainties:


•	the Company’s assumptions about energy markets


•	production levels


•	reserves levels


•	operating results


•	competitive conditions


•	technology


•	availability of capital resources, levels of capital expenditures, and other contractual obligations


•	supply and demand for, the price of, and the commercializing and transporting of natural gas, crude oil, natural gas liquids (NGLs), and other products or services


•	volatility in the commodity-futures market


•	weather


•	inflation


•	availability of goods and services, including unexpected changes in costs


•	drilling risks


•	future processing volumes and pipeline throughput


•	general economic conditions, either internationally or nationally or in the jurisdictions in which the Company or its subsidiaries are doing business


•	the Company’s inability to timely obtain or maintain permits, including those necessary for drilling and/or development projects


•	legislative or regulatory changes, including retroactive royalty or production tax regimes; hydraulic-fracturing regulation; deepwater drilling and permitting regulations; derivatives reform; changes in state, federal, and foreign income taxes; environmental regulation; environmental risks; and liability under federal, state, foreign, and local environmental laws and regulations

•

ability of BP Exploration & Production Inc. (BP) to meet its indemnification obligations to the Company for Deepwater Horizon events, including, among other things, damage claims arising under the Oil Pollution Act of 1990, claims for natural resource damages and associated damage-assessment costs, and any claims arising under the Operating Agreement for the Macondo well, as well as the ability of BP Corporation North America Inc. and BP p.l.c. to satisfy their guarantees of such indemnification obligations


•	impact of remaining claims related to the Deepwater Horizon events, including, but not limited to, fines, penalties, and punitive damages against the Company, for which it is not indemnified by BP


•	current and potential legal proceedings, or environmental or other obligations related to or arising from Tronox Incorporated (Tronox)


•	civil or political unrest or acts of terrorism in a region or country


•	creditworthiness and performance of the Company’s counterparties, including financial institutions, operating partners, and other parties


•	volatility in the securities, capital, or credit markets and related risks such as general credit, liquidity and interest-rate risk


•	the Company’s ability to successfully monetize select assets, repay its debt, and the impact of changes in the Company’s credit ratings


•	disruptions in international crude oil cargo shipping activities


•	physical, digital, internal, and external security breaches


•	supply and demand, technological, political, and commercial conditions associated with long-term development and production projects in domestic and international locations


•	other factors discussed below and elsewhere in “Risk Factors” and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates” included in the Company’s 2012 Annual Report on Form 10-K, this Form 10-Q, and in the Company’s other public filings, press releases, and discussions with Company management

The following discussion should be read together with the Consolidated Financial Statements and the Notes to Consolidated Financial Statements, which are included in this report in Part I, Item 1; the information set forth in Risk Factors under Part II, Item 1A; the Consolidated Financial Statements and the Notes to Consolidated Financial Statements, which are included in Part II, Item 8 of the 2012 Annual Report on Form 10-K; and the information set forth in the Risk Factors under Part I, Item 1A of the 2012 Annual Report on Form 10-K.

OVERVIEW

Anadarko is among the world’s largest independent exploration and production companies. Anadarko is engaged in the exploration, development, production, and marketing of natural gas, crude oil, condensate, and NGLs. The Company also engages in the gathering, processing, treating, and transporting of natural gas, crude oil, and NGLs. The Company has production and exploration activities worldwide, including activities in the United States, Algeria, Mozambique, Ghana, China, Kenya, Côte d’Ivoire, Liberia, Sierra Leone, Brazil, New Zealand, and other countries.

Significant operating and financial activities during the second quarter of 2013 include the following:

Overall


•	Anadarko’s second-quarter sales volumes totaled 750 thousand barrels of oil equivalent per day (MBOE/d), representing a 1% increase over the second quarter of 2012.


•	Anadarko’s second-quarter liquids sales volumes were 309 thousand barrels per day (MBbls/d), representing a 3% decrease from the second quarter of 2012 primarily due to timing of international cargo liftings; scheduled downtime for maintenance, well work, and natural production declines in the Gulf of Mexico; and ethane rejection in the Rocky Mountains Region (Rockies).

U.S. Onshore


•	U.S. onshore second-quarter sales volumes were 568 MBOE/d, representing a 12% increase from the second quarter of 2012, primarily due to increased sales volumes from the Wattenberg field and the Marcellus, Eagleford, and Haynesville shales, partially offset by 2013 ethane rejection in the Rockies and a natural decline in the Powder River basin.


•	Liquids sales volumes from the Wattenberg field averaged more than 60 MBbls/d, which represented an increase of more than 37% over the second quarter of 2012.


•	Liquids sales volumes from the Eagleford shale averaged 32 MBbls/d, which represented an increase of 62% over the second quarter of 2012.

Gulf of Mexico


•	Gulf of Mexico second-quarter sales volumes were 99 MBOE/d, representing a 25% decrease from the second quarter of 2012, primarily due to scheduled downtime for maintenance, well work, and natural production declines.


•	The Company drilled the successful Phobos exploration well (30% working interest) in the Sigsbee Escarpment block 39, encountering approximately 250 net feet of oil pay in the Lower Tertiary-aged reservoirs.


•	The Company drilled the successful Raptor exploration well (50% working interest) in the Desoto Canyon block 535, encountering approximately 150 net feet of high-quality oil pay.


•	The Company participated in the successful Yucatan exploration well (15% working interest) in the Walker Ridge block 95, encountering more than 120 net feet of high-quality oil pay.


•	The Company entered into a carried-interest arrangement that requires a third-party partner to fund $860 million of Anadarko’s capital costs to earn a 12.75% working interest in the Heidelberg development.


•	Anadarko and its partners officially sanctioned Heidelberg and expect to achieve first oil in mid-2016.


•	The Company successfully transported its 80,000-barrels-of-oil-per-day Lucius spar from the fabrication yard in Pori, Finland to Corpus Christi, Texas, with plans to install the spar in Keathley Canyon block 875 during the third quarter of 2013.

International


•	International second-quarter sales volumes were 71 MBOE/d, representing a 17% decrease from the second quarter of 2012, primarily due to timing of cargo liftings in Algeria and China.


•	The Company sold its first delivery of crude oil from the El Merk project in Algeria and the second oil train is being commissioned.


•	The Company successfully drilled the Orca-1 discovery well (36.5% working interest) in Offshore Area 1 in Mozambique, encountering approximately 190 net feet of natural-gas pay in a Paleocene fan system.


•	The Company drilled the successful Espadarte exploration well (36.5% working interest) in Offshore Area 1 in Mozambique, encountering approximately 280 net feet of natural-gas pay.


•	Anadarko and its partners received government approval for the Plan of Development for the Tweneboa/Enyenra/Ntomme deepwater oil project offshore Ghana.

Financial


•	Anadarko’s net income attributable to common stockholders totaled $929 million.


•	The Company generated $2.5 billion of cash flows from operations and ended the quarter with $4.6 billion of cash on hand.


•	Anadarko collected $248 million associated with the Algeria exceptional profits tax receivable.


•	Western Gas Partners, LP (WES), a consolidated subsidiary of the Company, issued approximately seven million common units to the public, raising net proceeds of $416 million.


•	WES reduced its outstanding borrowings under its five-year, $800 million senior unsecured revolving credit facility maturing in March 2016 (RCF) by $135 million.

The following discussion pertains to Anadarko’s results of operations, financial condition, and changes in financial condition. Any increases or decreases “for the three months ended June 30, 2013,” refer to the comparison of the three months ended June 30, 2013, to the three months ended June 30, 2012, and any increases or decreases “for the six months ended June 30, 2013,” refer to the comparison of the six months ended June 30, 2013, to the six months ended June 30, 2012. The primary factors that affect the Company’s results of operations include commodity prices for natural gas, crude oil, and NGLs; sales volumes; the Company’s ability to discover additional oil and natural-gas reserves; the cost of finding such reserves; and operating costs.

RESULTS OF OPERATIONS



	Three Months Ended June 30,						Six Months Ended June 30,
millions except per-share amounts	2013			2012			2013			2012
Financial Results
Revenues and other	$	3,497		$	3,222		$	7,390		$	6,669
Costs and expenses	2,357			3,501			4,961			4,246
Other (income) expense	(386		)	(373		)	(37		)	(206		)
Income tax expense (benefit)	567			164			1,023			516
Net income (loss) attributable to common stockholders	$	929		$	(89	)	$	1,389		$	2,067
Net income (loss) per common share attributable to common stockholders—diluted	$	1.83		$	(0.18	)	$	2.74		$	4.10
Average number of common shares outstanding—diluted	504			500			504			501

Operating Results
Adjusted EBITDAX ⁽¹⁾	$	2,244		$	2,230		$	4,921		$	4,485
Sales volumes (MMBOE)	69			68			140			132

________________________________________________________________________________________________________

MMBOE—million barrels of oil equivalent


⁽¹⁾	See Operating Results—Segment Analysis—Adjusted EBITDAX for a description of Adjusted EBITDAX, which is not a U.S. Generally Accepted Accounting Principles (GAAP) measure, and for a reconciliation of Adjusted EBITDAX to income (loss) before income taxes, which is presented in accordance with GAAP.

FINANCIAL RESULTS

Net Income (Loss) Attributable to Common Stockholders For the three months ended June 30, 2013, Anadarko’s net income attributable to common stockholders totaled $929 million, or $1.83 per share (diluted), compared to a net loss attributable to common stockholders of $89 million, or $0.18 per share (diluted), for the three months ended June 30, 2012. Anadarko’s net loss for the three months ended June 30, 2012, included $844 million for impairments of certain unproved properties. For the six months ended June 30, 2013, Anadarko’s net income attributable to common stockholders totaled $1.4 billion, or $2.74 per share (diluted), compared to net income attributable to common stockholders of $2.1 billion, or $4.10 per share (diluted), for the same period of 2012. Anadarko’s net income for the six months ended June 30, 2012, included $1.8 billion related to the favorable resolution of the Algerian exceptional profits tax dispute with Sonatrach and $844 million for impairments of certain unproved properties.

Sales Revenues and Volumes



	Three Months Ended June 30,						Six Months Ended June 30,
millions except percentages	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
Sales Revenues
Natural-gas sales	$	935	89	%	$	496	$	1,742	63	%	$	1,069
Oil and condensate sales	1,995		(10	)	2,222		4,372		(2	)	4,466
Natural-gas liquids sales	261		(7	)	282		564		(10	)	624
Total	$	3,191	6		$	3,000	$	6,678	8		$	6,159

Anadarko’s total sales revenues increased for the three months ended June 30, 2013, primarily due to higher sales volumes for natural gas and NGLs, and higher average natural-gas prices, partially offset by lower average crude-oil and NGLs prices, and lower sales volumes for crude oil. Anadarko’s total sales revenues increased for the six months ended June 30, 2013, primarily due to higher sales volumes for all products and higher average natural-gas prices, partially offset by lower average crude-oil and NGLs prices.



	Three Months Ended June 30,
millions	Natural Gas		Oil and Condensate			NGLs			Total
2012 sales revenues	$	496	$	2,222		$	282		$	3,000
Changes associated with sales volumes	21		(144		)	25			(98		)
Changes associated with prices	418		(83		)	(46		)	289
2013 sales revenues	$	935	$	1,995		$	261		$	3,191



	Six Months Ended June 30,
millions	Natural Gas		Oil and Condensate			NGLs			Total
2012 sales revenues	$	1,069	$	4,466		$	624		$	6,159
Changes associated with sales volumes	74		154			57			285
Changes associated with prices	599		(248		)	(117		)	234
2013 sales revenues	$	1,742	$	4,372		$	564		$	6,678



	Three Months Ended June 30,				Six Months Ended June 30,
Sales Volumes	2013	Inc/(Dec) vs. 2012		2012	2013	Inc/(Dec) vs. 2012		2012
Barrels of Oil Equivalent (MMBOE except percentages)
United States	62	3	%	60	124	7	%	116
International	7	(17	)	8	16	—		16
Total	69	1		68	140	6		132

Barrels of Oil Equivalent per Day (MBOE/d except percentages)
United States	679	3	%	657	687	8	%	639
International	71	(17	)	85	84	—		84
Total	750	1		742	771	7		723

Sales volumes represent actual production volumes adjusted for changes in commodity inventories. Anadarko employs marketing strategies to minimize market-related shut-ins, maximize realized prices, and manage credit-risk exposure. For additional information, see Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q and Other (Income) Expense—(Gains) Losses on Derivatives, net. Production of natural gas, crude oil, and NGLs is usually not affected by seasonal swings in demand.

Natural-Gas Sales Volumes, Average Prices, and Revenues



	Three Months Ended June 30,						Six Months Ended June 30,
	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
United States
Sales volumes—Bcf	241		4	%	230		483		7	%	450
MMcf/d	2,647		4		2,544		2,668		8		2,480
Price per Mcf	$	3.88	80		$	2.15	$	3.61	52		$	2.37
Natural-gas sales revenues (millions)	$	935	89		$	496	$	1,742	63		$	1,069

_______________________________________________________________________________

Bcf—billion cubic feet

MMcf/d—million cubic feet per day

Mcf—thousand cubic feet

The Company’s natural-gas sales volumes increased 103 MMcf/d for the three months ended June 30, 2013, and 188 MMcf/d for the six months ended June 30, 2013. Sales volumes for the Southern and Appalachia Region increased 254 MMcf/d for the three months ended June 30, 2013, and 268 MMcf/d for the six months ended June 30, 2013, primarily due to infrastructure expansions in 2012 that allowed the Company to bring wells online in the Eagleford and Marcellus shales, as well as new wells drilled in the liquids-rich Haynesville shale. These increases were partially offset by lower sales volumes in the Gulf of Mexico of 78 MMcf/d for the three months ended June 30, 2013, and 38 MMcf/d for the six months ended June 30, 2013, primarily due to natural production declines. Also, sales volumes for the Rockies decreased 73 MMcf/d for the three months ended June 30, 2013, and 42 MMcf/d for the six months ended June 30, 2013, primarily due to a natural production decline in the Powder River basin, partially offset by higher natural-gas sales volumes due to increased horizontal drilling in the Wattenberg field.

The average natural-gas price Anadarko received increased for the three and six months ended June 30, 2013, due to increased U.S. residential and commercial demand. This contributed to a reduction in overall U.S. storage levels, which are in line with the 5-year average.

Crude-Oil and Condensate Sales Volumes, Average Prices, and Revenues



	Three Months Ended June 30,						Six Months Ended June 30,
	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
United States
Sales volumes—MMBbls	14		(1	)%	15		28		6	%	27
MBbls/d	155		(1	)	156		157		6		148
Price per barrel	$	94.99	(3	)	$	98.20	$	96.17	(5	)	$	101.76
International
Sales volumes—MMBbls	7		(17	)%	8		16		—	%	16
MBbls/d	71		(17	)	85		84		—		84
Price per barrel	$	102.05	(4	)	$	106.77	$	107.89	(5	)	$	113.30
Total
Sales volumes—MMBbls	21		(6	)%	23		44		3	%	43
MBbls/d	226		(6	)	241		241		4		232
Price per barrel	$	97.21	(4	)	$	101.22	$	100.26	(5	)	$	105.94
Oil and condensate sales revenues (millions)	$	1,995	(10	)	$	2,222	$	4,372	(2	)	$	4,466

_______________________________________________________________________________

MMBbls—million barrels

MBbls/d—thousand barrels per day

Anadarko’s total crude-oil and condensate sales volumes decreased 15 MBbls/d for the three months ended June 30, 2013. Sales volumes in the Gulf of Mexico decreased 19 MBbls/d due to scheduled downtime for maintenance, well work, and natural production declines. Internationally, sales volumes decreased 16 MBbls/d in Algeria and 8 MBbls/d in China due to timing of cargo liftings, partially offset by a 10 MBbls/d increase associated with an additional cargo lifting in Ghana as a result of enhanced production due to successful acid stimulations in 2012 and additional Phase 1A Jubilee wells brought online. Sales volumes for the Rockies increased 14 MBbls/d primarily due to increased horizontal drilling in the Wattenberg field. Sales volumes for the Southern and Appalachia Region increased 6 MBbls/d as a result of horizontal drilling and infrastructure expansions in the Eagleford shale.

Anadarko’s total crude-oil and condensate sales volumes increased 9 MBbls/d for the six months ended June 30, 2013. Increased horizontal drilling in the Wattenberg field increased sales volumes in the Rockies by 16 MBbls/d. Horizontal drilling and infrastructure expansions in the Eagleford shale led to a 7 MBbls/d sales-volume improvement in the Southern and Appalachia Region. Sales volumes in the Gulf of Mexico decreased by 11 MBbls/d primarily due to scheduled downtime for maintenance, well work, and natural production declines.

Anadarko’s average crude-oil price received decreased for the three and six months ended June 30, 2013, due to U.S.-dollar strength and renewed economic growth concerns in Europe and China, which outweighed continuing supply disruption concerns associated with political and civil unrest in the Middle East and North Africa.

Natural-Gas Liquids Sales Volumes, Average Prices, and Revenues



	Three Months Ended June 30,						Six Months Ended June 30,
	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
United States
Sales volumes—MMBbls	7		9	%	7		15		9	%	14
MBbls/d	83		9		77		85		8		78
Price per barrel	$	34.33	(15	)	$	40.41	$	36.29	(17	)	$	43.82
Natural-gas liquids sales revenues (millions)	$	261	(7	)	$	282	$	564	(10	)	$	624

NGLs sales represent revenues from the sale of product derived from the processing of Anadarko’s natural-gas production. The Company’s NGLs sales volumes increased by 6 MBbls/d for the three months ended June 30, 2013, and 7 MBbls/d for the six months ended June 30, 2013. Sales volumes for the Southern and Appalachia Region increased 15 MBbls/d for the three months ended June 30, 2013, and 12 MBbls/d for the six months ended June 30, 2013, as a result of continued horizontal drilling and 2012 infrastructure expansion in the Eagleford shale, and horizontal drilling in the Haynesville shale. This increase was partially offset by lower sales volumes in the Rockies of 6 MBbls/d for the three months ended June 30, 2013, and 5 MBbls/d for the six months ended June 30, 2013, primarily due to ethane rejection in 2013.

Anadarko’s average NGLs price received decreased for the three and six months ended June 30, 2013, primarily due to lower market prices for ethane and propane due to higher U.S. inventory levels. Ethane production capacity remains elevated relative to demand, resulting in ethane rejection to balance the market.

Gathering, Processing, and Marketing Margin



	Three Months Ended June 30,						Six Months Ended June 30,
millions except percentages	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
Gathering, processing, and marketing sales	$	249	25	%	$	200	$	480	6	%	$	453
Gathering, processing, and marketing expenses	222		25		178		421		15		367
Margin	$	27	23		$	22	$	59	(31	)	$	86

The gathering, processing, and marketing margin increased by $5 million for the three months ended June 30, 2013. This increase is due to higher gathering revenue from increased throughput across several of Anadarko’s systems and higher marketing margins.

The gathering, processing, and marketing margin decreased by $27 million for the six months ended June 30, 2013, primarily due to reduced natural-gas processing margins. This decrease was partially offset by increased gathering revenue discussed above and higher marketing margins. Also, for the three and six months ended June 30, 2013, the gathering, processing, and marketing margin decreased due to higher transportation expenses.

Gains (Losses) on Divestitures and Other, net

Gains (losses) on divestitures and other, net increased by $35 million for the three months ended June 30, 2013, primarily due to a 2013 gain on divestiture of hard-mineral interests in Battle Mountain, Nevada of $12 million and 2012 losses associated with divestitures of oil and gas properties in the United States of $13 million.

Gains (losses) on divestitures and other, net increased by $175 million for the six months ended June 30, 2013, primarily due to a $140 million gain associated with the Company’s divestiture of its interests in a soda ash joint venture during the first quarter of 2013 and gains (losses) on divestitures discussed above. The Company divested its interests in the soda ash joint venture for $310 million and potential additional consideration based on future revenue. The Company retained its royalty interest in minerals, such as natural soda ash, mined from the Company’s Land Grant.

Costs and Expenses



	Three Months Ended June 30,						Six Months Ended June 30,
	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
Oil and gas operating (millions)	$	245	(2	)%	$	249	$	492	—	%	$	491
Oil and gas operating—per BOE	3.59		(2	)	3.68		3.52		(6	)	3.73
Oil and gas transportation and other (millions)	253		13		223		508		10		463
Oil and gas transportation and other—per BOE	3.70		12		3.30		3.64		4		3.51

For the three months ended June 30, 2013, oil and gas operating expenses decreased by $4 million due to lower platform maintenance costs primarily in the Gulf of Mexico, while the related per barrel of oil equivalent (BOE) costs decreased by $0.09 as a result of increased sales volumes.

For the six months ended June 30, 2013, oil and gas operating expenses were flat compared to the six months ended June 30, 2012, while the per BOE costs decreased by $0.21 due to increased sales volumes.

Oil and gas transportation and other expenses increased by $30 million for the three months ended June 30, 2013, and $45 million for the six months ended June 30, 2013, primarily due to higher gas-gathering and transportation costs attributable to higher volumes and increased costs related to growth in the Company’s U.S. onshore asset base. For the three months ended June 30, 2013, oil and gas transportation and other expenses per BOE increased by $0.40 primarily due to the higher costs discussed above. For the six months ended June 30, 2013, oil and gas transportation and other expenses per BOE increased by $0.13 primarily due to the higher costs discussed above, partially offset by increased sales volumes.



	Three Months Ended June 30,				Six Months Ended June 30,
millions	2013		2012		2013		2012
Exploration Expense
Dry hole expense	$	66	$	115	$	224	$	204
Impairments of unproved properties	20		923		39		983
Geological and geophysical expenses	23		14		60		49
Exploration overhead and other	69		69		119		129
Total exploration expense	$	178	$	1,121	$	442	$	1,365

For the three months ended June 30, 2013, unproved property impairments decreased by $903 million. During the second quarter of 2012, the Company recognized $720 million associated with the impairment of unproved Powder River coalbed methane properties in the Rockies primarily due to lower natural-gas prices and $124 million associated with the impairment of an unproved Gulf of Mexico natural-gas property that the Company did not plan to pursue under the forecasted natural-gas price environment. In addition, unproved property impairments for the three months ended June 30, 2013, decreased by $36 million as a result of a 2013 change in the Company’s estimated success rate associated with certain unproved Gulf of Mexico properties. For the three months ended June 30, 2013, dry hole expense decreased by $49 million primarily associated with 2012 dry hole expense for wells in the Gulf of Mexico, Sierra Leone, and Ghana, partially offset by 2013 dry hole expense for wells in Côte d’Ivoire and Mozambique.

For the six months ended June 30, 2013, unproved property impairments decreased by $944 million primarily due to the 2012 impairments of unproved properties discussed above and a decrease of $72 million as a result of a 2013 change in the Company’s estimated success rate associated with certain unproved Gulf of Mexico properties. For the six months ended June 30, 2013, dry hole expense increased by $20 million primarily due to 2013 dry hole expense for wells in Sierra Leone, Kenya, and Mozambique, partially offset by 2012 dry hole expense for wells in the Gulf of Mexico, Alaska, and Brazil.



	Three Months Ended June 30,						Six Months Ended June 30,
millions except percentages	2013		Inc/(Dec) vs. 2012		2012		2013		Inc/(Dec) vs. 2012		2012
General and administrative	$	260	(1	)%	$	262	$	532	—	%	$	531
Depreciation, depletion, and amortization	940		(8	)	1,027		1,962		—		1,957
Other taxes	245		(25	)	326		525		(25	)	703
Impairments	10		(91	)	112		39		(76	)	162

For the three months ended June 30, 2013, general and administrative (G&A) expense decreased by $2 million primarily due to lower legal and consulting fees of $26 million, partially offset by higher employee-related expenses of $23 million related to operational expansions and increased employee-benefit-related expenses. For the six months ended June 30, 2013, G&A expense increased by $1 million primarily due to $50 million of higher employee-related expenses as a result of operational expansions and increased employee-benefit-related expenses, partially offset by lower legal and consulting fees of $45 million and other G&A expenses.

For the three months ended June 30, 2013, depreciation, depletion, and amortization (DD&A) expense decreased by $87 million primarily due to the 2012 accelerated depletion of certain fields in the Gulf of Mexico. For the six months ended June 30, 2013, DD&A increased by $5 million primarily due to higher sales volumes in 2013, partially offset by the accelerated depletion discussed above.

For the three months ended June 30, 2013, other taxes decreased by $81 million primarily due to decreased sales volumes in Algeria and China and lower crude-oil prices, resulting in lower Algerian exceptional profits taxes of $54 million and lower Chinese windfall profits taxes of $22 million. For the six months ended June 30, 2013, other taxes decreased by $178 million primarily related to lower Algerian exceptional profits taxes of $126 million due to a lower Algeria effective tax rate resulting from the resolution of the Algeria exceptional profits tax dispute, decreased sales volumes, and lower crude-oil prices. In addition, lower sales volumes and crude-oil prices resulted in a $30 million decrease in U.S. production and severance taxes primarily in Alaska and a $29 million decrease in Chinese windfall profits taxes.

Impairment expense of $10 million for the three months ended June 30, 2013, related to the Company’s Venezuelan cost-method investment due to declines in estimated recoverable value. Impairment expense for the three months ended June 30, 2012, included $79 million related to certain onshore domestic oil and gas exploration and production properties and $5 million related to midstream properties due to lower natural-gas prices, $17 million related to downward reserves revisions for a Gulf of Mexico property that was near the end of its economic life, and $11 million related to the Company’s Venezuelan cost-method investment due to declines in estimated recoverable value.

Impairment expense for the six months ended June 30, 2013, included $29 million related to a midstream property that was impaired due to a reduction in estimated future cash flows and $10 million related to the Company’s Venezuelan cost-method investment, as discussed above. Impairment expense for the six months ended June 30, 2012, included $112 million of impairments recognized in the second quarter of 2012, as discussed above, and $50 million related to downward reserves revisions for a Gulf of Mexico property that was near the end of its economic life.



	Three Months Ended June 30,				Six Months Ended June 30,
millions	2013		2012		2013		2012
Algeria exceptional profits tax settlement	$	—	$	—	$	33	$	(1,804	)
Deepwater Horizon settlement and related costs	4		3		7		11

In March 2012, Anadarko and Sonatrach resolved the exceptional profits tax dispute. The resolution provided for delivery to the Company of crude oil valued at approximately $1.7 billion and the elimination of $62 million of previously recorded and unpaid transportation charges. The Company recognized a $1.8 billion credit in the Costs and Expenses section of the Consolidated Statement of Income for the three months ended June 30, 2012, to reflect the effect of this agreement for previously recorded expenses. At June 30, 2013, the Company had collected approximately $1.7 billion associated with the Algeria exceptional profits tax receivable and expects to collect the remaining $32 million in the third quarter of 2013. In March 2013, the Company revised its estimate of income tax expense related to the elimination of previously recorded and unpaid transportation charges and recognized a $33 million unfavorable adjustment to the settlement, which was offset by an equivalent income tax benefit also recognized in March 2013.

For the three and six months ended June 30, 2013 and 2012, Deepwater Horizon settlement and related costs included legal expenses and related costs associated with the Deepwater Horizon events. See Note 12—Contingencies—Deepwater Horizon Events in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

Other (Income) Expense



	Three Months Ended June 30,								Six Months Ended June 30,
millions except percentages	2013			Inc/(Dec) vs. 2012		2012			2013			Inc/(Dec) vs. 2012		2012
Interest Expense
Current debt, long-term debt, and other	$	238		1	%	$	236		$	470		(3	)%	$	486
Capitalized interest	(66		)	(43	)	(46		)	(134		)	(22	)	(110		)
Interest expense	$	172		(9	)	$	190		$	336		(11	)	$	376

Interest expense decreased by $18 million for the three months ended June 30, 2013, and $40 million for the six months ended June 30, 2013. These decreases were primarily due to an increase in capitalized interest related to higher construction-in-progress balances for long-term capital projects and the repayment of outstanding borrowings during 2012 associated with the five-year, $5.0 billion senior secured revolving credit facility maturing in September 2015 ($5.0 billion Facility). For additional information regarding the Company’s financing activities, see Liquidity and Capital Resources.



	Three Months Ended June 30,						Six Months Ended June 30,
millions	2013			2012			2013			2012
(Gains) Losses on Derivatives, net
Commodity derivatives
Realized (gains) losses
Natural gas	$	16		$	(224	)	$	(51	)	$	(394	)
Oil and condensate	(34		)	(36		)	(16		)	(3		)
Natural gas liquids	(3		)	(3		)	(5		)	(3		)
Total realized (gains) losses	(21		)	(263		)	(72		)	(400		)
Unrealized (gains) losses
Natural gas	(258		)	288			11			202
Oil and condensate	(110		)	(414		)	(50		)	(241		)
Natural gas liquids	(5		)	(31		)	—			(29		)
Total unrealized (gains) losses	(373		)	(157		)	(39		)	(68		)
Total (gains) losses on commodity derivatives, net	(394		)	(420		)	(111		)	(468		)
Interest-rate and other derivatives
Realized (gains) losses	—			2			—			2
Unrealized (gains) losses	(262		)	374			(354		)	138
Total (gains) losses on interest-rate and other derivatives, net	(262		)	376			(354		)	140
Total (gains) losses on derivatives, net	$	(656	)	$	(44	)	$	(465	)	$	(328	)

The Company enters into commodity derivatives to manage the risk of a decrease in the market prices for its anticipated sales of production. The change in (gains) losses on commodity derivatives, net includes the impact of derivatives entered into or settled within each period and price changes related to positions open at June 30 of both years. For additional information on (gains) losses on commodity derivatives, see Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Anadarko enters into interest-rate swaps to fix or float interest rates on existing or anticipated indebtedness to manage exposure to unfavorable interest-rate changes. The fair value of the Company’s interest-rate swap portfolio increases (decreases) when interest rates increase (decrease). For additional information, see Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.



	Three Months Ended June 30,								Six Months Ended June 30,
millions except percentages	2013			Inc/(Dec) vs. 2012		2012			2013			Inc/(Dec) vs. 2012		2012
Other (Income) Expense, net
Interest income	$	(2	)	—	%	$	(2	)	$	(4	)	—	%	$	(4	)
Other	100			(119	)	(517		)	96			(138	)	(250		)
Total other (income) expense, net	$	98		(119	)	$	(519	)	$	92		(136	)	$	(254	)

Total other income decreased by $617 million for the three months ended June 30, 2013, and $346 million for the six months ended June 30, 2013, primarily due to the 2012 reversal of a Tronox-related contingent loss. See Note 12—Contingencies—Tronox Litigation in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q. In addition, during the second quarter of 2013, the Company recognized a pretax loss of $141 million related to the cost to decommission wells and production facilities previously sold to a third party. In June 2013, as a result of a Chapter 11 bankruptcy declaration by the third party, the U.S. Department of the Interior ordered Anadarko to perform the decommissioning of the facility and related wells. These wells and production facilities are no longer owned by the Company nor related to its current operations. Anadarko expects to complete decommissioning of the production facilities in 2014 and the wells in 2015. These decreases were partially offset by the second-quarter 2013 reversal of the $56 million tax indemnification liability associated with the 2006 sale of the Company’s Canadian subsidiary. The indemnity was reversed as a result of certain Canadian tax legislative changes.

Income Tax Expense



	Three Months Ended June 30,						Six Months Ended June 30,
millions except percentages	2013			2012			2013			2012
Income tax expense (benefit)	$	567		$	164		$	1,023		$	516
Effective tax rate	37		%	174		%	41		%	20		%

Net Income Attributable to Noncontrolling Interests

The Company’s net income attributable to noncontrolling interests of $30 million for the three months ended June 30, 2013, and $54 million for the six months ended June 30, 2013, primarily related to the public ownership of a 54.5% limited partner interest in WES and 9.0% limited partner interest in Western Gas Equity Partners, LP (WGP) at June 30, 2013. The Company’s net income attributable to noncontrolling interests of $19 million for the three months ended June 30, 2012, and $46 million for the six months ended June 30, 2012, primarily related to the public ownership of a 56.6% limited partner interest in WES at June 30, 2012.

OPERATING RESULTS

Segment Analysis—Adjusted EBITDAX To assess the performance of Anadarko’s operating segments, the chief operating decision maker analyzes Adjusted EBITDAX. The Company defines Adjusted EBITDAX as income (loss) before income taxes, exploration expense, DD&A, impairments, interest expense, unrealized (gains) losses on derivatives, net, realized (gains) losses on interest-rate and other derivatives, net, and certain items not related to the Company’s normal operations, less net income attributable to noncontrolling interests. During the periods presented, these items included Deepwater Horizon settlement and related costs, Algeria exceptional profits tax settlement, Tronox-related contingent loss, and certain other nonoperating items included in other (income) expense, net. The Company’s definition of Adjusted EBITDAX, which is not a GAAP measure, excludes exploration expense, as it is not an indicator of operating efficiency for a given reporting period. However, exploration expense is monitored by management as part of costs incurred in exploration and development activities. Similarly, DD&A and impairments are excluded from Adjusted EBITDAX as a measure of segment operating performance because capital expenditures are evaluated at the time capital costs are incurred. Adjusted EBITDAX also excludes interest expense to allow for assessment of segment operating results without regard to Anadarko’s financing methods or capital structure. Finally, unrealized (gains) losses on derivatives, net and realized (gains) losses on interest-rate and other derivatives, net are excluded from Adjusted EBITDAX because these (gains) losses are not considered a measure of asset operating performance. Management believes that the presentation of Adjusted EBITDAX provides information useful in assessing the Company’s financial condition and results of operations and that Adjusted EBITDAX is a widely accepted financial indicator of a company’s ability to incur and service debt, fund capital expenditures, and make distributions to stockholders.

Adjusted EBITDAX, as defined by Anadarko, may not be comparable to similarly titled measures used by other companies. Therefore, Anadarko’s consolidated Adjusted EBITDAX should be considered in conjunction with net income (loss) attributable to common stockholders and other performance measures prepared in accordance with GAAP, such as operating income or cash flows from operating activities. Adjusted EBITDAX has important limitations as an analytical tool because it excludes certain items that affect net income (loss) attributable to common stockholders and net cash provided by operating activities. Adjusted EBITDAX should not be considered in isolation or as a substitute for an analysis of Anadarko’s results as reported under GAAP. Below is a reconciliation of consolidated Adjusted EBITDAX to income (loss) before income taxes, and consolidated Adjusted EBITDAX by reporting segment.

Adjusted EBITDAX



	Three Months Ended June 30,								Six Months Ended June 30,
millions except percentages	2013			Inc/(Dec) vs. 2012		2012			2013			Inc/(Dec) vs. 2012		2012
Income (loss) before income taxes	$	1,526		NM		$	94		$	2,466		(6	)%	$	2,629
Exploration expense	178			(84	)%	1,121			442			(68	)	1,365
DD&A	940			(8	)	1,027			1,962			—		1,957
Impairments	10			(91	)	112			39			(76	)	162
Interest expense	172			(9	)	190			336			(11	)	376
Unrealized (gains) losses on derivatives, net	(641		)	NM		225			(395		)	NM		83
Realized (gains) losses on interest-rate and other derivatives, net	—			(100	)	2			—			(100	)	2
Deepwater Horizon settlement and related costs	4			33		3			7			(36	)	11
Algeria exceptional profits tax settlement	—			NM		—			33			NM		(1,804		)
Tronox-related contingent loss	—			100		(525		)	—			100		(250		)
Certain other nonoperating items	85			NM		—			85			NM		—
Less net income attributable to noncontrolling interests	30			58		19			54			17		46
Consolidated Adjusted EBITDAX	$	2,244		1		$	2,230		$	4,921		10		$	4,485

Adjusted EBITDAX by reporting segment
Oil and gas exploration and production	$	2,269		11	%	$	2,038		$	4,795		15	%	$	4,168
Midstream	114			7		107			239			6		226
Marketing	(44		)	(2	)	(43		)	(77		)	(26	)	(61		)
Other and intersegment eliminations	(95		)	(174	)	128			(36		)	(124	)	152

________________________________________________________________________________

NM—not meaningful

Oil and Gas Exploration and Production Adjusted EBITDAX for the three months ended June 30, 2013, increased primarily due to higher sales volumes for natural gas and NGLs; higher natural-gas prices; and lower other taxes primarily from lower crude-oil prices and decreased sales volumes in Algeria, China, and Alaska. These increases to Adjusted EBITDAX were partially offset by lower crude-oil volumes and decreased crude-oil and NGLs prices. Adjusted EBITDAX for the six months ended June 30, 2013, increased primarily due to higher sales volumes for all products, higher natural-gas prices, and lower other taxes primarily from a lower Algerian effective tax rate, decreased crude-oil prices, and lower sales volumes in Algeria, China, and Alaska. These increases to Adjusted EBITDAX were partially offset by lower crude-oil and NGLs prices.

Midstream The increase in Adjusted EBITDAX for the three and six months ended June 30, 2013, is primarily due to higher gathering revenue as a result of increased throughput across several of Anadarko’s systems. This increase was partially offset by lower natural-gas processing margins for the six months ended June 30, 2013.

Marketing Marketing earnings primarily represent the margin earned on sales of natural gas, oil, and NGLs purchased from third parties. For the three and six months ended June 30, 2013, Adjusted EBITDAX decreased primarily due to higher transportation expenses, partially offset by higher margins primarily associated with NGLs sales.

Other and Intersegment Eliminations Other and intersegment eliminations consist primarily of corporate costs, realized gains and losses on commodity derivatives, and income from hard-minerals royalties. The decrease in Adjusted EBITDAX for the three and six months ended June 30, 2013, was primarily due to lower realized gains on commodity derivatives in 2013. Also, for the six months ended June 30, 2013, a $140 million gain associated with the Company’s divestiture of its interest in a soda ash joint venture partially offset the decrease in Adjusted EBITDAX. See Other (Income) Expense.

LIQUIDITY AND CAPITAL RESOURCES

Overview Anadarko generates cash needed to fund capital expenditures, debt-service obligations, and dividend payments primarily from operating activities, and enters into debt and equity transactions to maintain the desired capital structure and to finance acquisition opportunities. Liquidity may also be enhanced through asset divestitures and joint ventures that reduce future capital expenditure requirements.

Consistent with this approach, during the six months ended June 30, 2013, cash flows from operating activities were the primary source of capital investment funding. In addition, the Company collected $698 million associated with the Algeria exceptional profits tax receivable during the six months ended June 30, 2013, and expects to collect the remaining $32 million in the third quarter of 2013. The Company continuously monitors its liquidity needs, coordinates its capital expenditure program with its expected cash flows and projected debt-repayment schedule, and evaluates available funding alternatives in light of current and expected conditions.

At June 30, 2013, Anadarko had no scheduled debt maturities for the remainder of 2013 and $775 million of scheduled debt maturities in 2014. However, Anadarko’s $500 million aggregate principal amount of 7.625% Senior Notes due March 2014, $275 million aggregate principal amount of 5.750% Senior Notes due June 2014, and Zero-Coupon Senior Notes due 2036, which can be put to the Company in October 2013 for the then-accreted value of $718 million, are classified as long-term debt on the Company’s Consolidated Balance Sheets, as the Company has the ability and intent to refinance these obligations using long-term debt. The Company has a variety of funding sources available, including cash on hand, an asset portfolio that provides ongoing cash-flow-generating capacity, opportunities for liquidity enhancement through divestitures and joint-venture arrangements, and the Company’s $5.0 billion Facility. Management believes that the Company’s liquidity position, asset portfolio, and continued strong operating and financial performance provide the necessary financial flexibility to fund the Company’s current and long-term operations.

Revolving Credit Facility Obligations incurred under the $5.0 billion Facility, as well as obligations Anadarko has to lenders or their affiliates pursuant to certain derivative instruments as discussed in Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q, are guaranteed by certain of the Company’s wholly owned domestic subsidiaries, and are secured by a perfected first-priority security interest in certain exploration and production assets located in the United States and 65% of the capital stock of certain wholly owned foreign subsidiaries. At June 30, 2013, the Company had no outstanding borrowings under the $5.0 billion Facility, there were no restrictions on its ability to utilize this borrowing capacity, and the Company was in compliance with all applicable covenants.

WES Funding Sources WES uses cash flows from operations to fund ongoing operations (including capital investments in the ordinary course of business), service its debt, and make distributions to its equity holders. As needed, WES supplements cash generated from its operating activities with proceeds from debt or equity issuances or borrowings under its RCF.

At June 30, 2013, WES was in compliance with all covenants contained in its RCF, had outstanding borrowings under the RCF of $250 million at an interest rate of 1.70%, and had available borrowing capacity of $537 million ($800 million maximum capacity, less $250 million of outstanding borrowings and $13 million of outstanding letters of credit). See Financing Activities below.

Insurance Coverage and Other Indemnities Anadarko maintains property and casualty insurance that includes coverage for physical damage to the Company's properties, blowout/control of a well, restoration and redrill, sudden and accidental pollution, third-party liability, workers' compensation and employers' liability, and other risks. Anadarko's insurance coverage includes deductibles that must be met prior to recovery. Additionally, the Company's insurance is subject to exclusions and limitations, and there is no assurance that such coverage will adequately protect the Company against liability or loss from all potential consequences and damages.

The Company's current insurance coverage includes: (a) $300 million per occurrence from Oil Insurance Limited (OIL) for physical damage to Anadarko's properties on a replacement cost basis, blowout/control of well, redrill, and sudden and accidental pollution; (b) $700 million per occurrence from the commercial markets for the items described in (a) above, which is in excess of the OIL coverage and which follows the form of OIL coverage with a few exceptions; (c) $400 million, which scales to Anadarko's working interest, for third-party liabilities including sudden and accidental pollution and aviation liability; and (d) $275 million for aircraft liability (in addition to the third-party liability limits described in (c) above). Anadarko carries no coverage for loss of production income from any of the Company’s facilities or for any losses that result from the effects of a named windstorm, for physical damage to the Company's properties, blowout/control of a well, or restoration and redrill.

Anadarko's property and casualty insurance policies renew in June of each year. At the next renewal date scheduled for June 2014, the Company may not be able to secure similar coverage for the same costs, if at all. Future insurance coverage costs for the oil and gas industry could increase and may include higher deductibles or retentions. In addition, some forms of insurance may become unavailable in the future or unavailable on terms that the Company considers economically acceptable.

The Company's service agreements, including drilling contracts, generally indemnify Anadarko for injuries and death to employees of the service provider and subcontractors hired by the service provider as well as for property damage suffered by the service provider and its contractors. Also, these service agreements generally indemnify Anadarko for pollution originating from the equipment of any contractors or subcontractors hired by the service provider.

Sources of Cash

Operating Activities Anadarko’s cash flows from operating activities during the six months ended June 30, 2013, was $5.0 billion, compared to $3.9 billion for the same period of 2012. Cash flows for 2013 increased primarily due to higher sales volumes, higher average natural-gas prices, the favorable impact of changes in working capital items, and cash collected associated with the Algeria exceptional profits tax receivable, but were partially offset by lower average crude-oil and NGLs prices.

One of the primary sources of variability in the Company’s cash flows from operating activities is fluctuations in commodity prices, which Anadarko partially mitigates by entering into commodity derivatives. Sales-volume changes also impact cash flow, but have not been as volatile as commodity prices. Anadarko’s cash flows from operating activities are also dependent on the costs related to continued operations and debt service.

Investing Activities During the six months ended June 30, 2013, Anadarko received pretax proceeds of $418 million related to several property divestiture transactions, including the divestiture of its interests in a soda ash joint venture.

Financing Activities During the six months ended June 30, 2013, Anadarko’s consolidated subsidiary, WES, borrowed $495 million under its RCF primarily to fund the acquisition of a 33.75% interest in certain gas-gathering systems, located in the Marcellus shale in north-central Pennsylvania, in separate transactions with Anadarko and a third party. In May 2013, WES issued approximately seven million common units to the public, raising net proceeds of $416 million, which were used to repay a portion of outstanding RCF borrowings and for other general partnership purposes, including the funding of WES’s capital expenditures.

Uses of Cash

Anadarko invests significant capital to develop, acquire, and explore for oil and natural-gas resources and to expand its midstream infrastructure, and also utilizes cash to fund ongoing operating costs, capital contributions to equity subsidiaries, debt repayments, and distributions to its shareholders.

Capital Expenditures The following presents the Company’s capital expenditures by category:



	Six Months Ended June 30,
millions	2013		2012
Property acquisition—exploration	$	94	$	96
Exploration	729		809
Development	1,850		1,938
Capitalized interest	117		100
Total oil and gas capital expenditures	2,790		2,943
Gathering, processing, and marketing and other ⁽¹⁾	823		656
Total capital expenditures ⁽²⁾	$	3,613	$	3,599

________________________________________________________________________________________


⁽¹⁾	Includes WES capital expenditures of $437 million for the six months ended June 30, 2013, and $221 million for the six months ended June 30, 2012.


⁽²⁾	Capital expenditures in the table above are presented on an accrual basis. Additions to properties and equipment on the Company’s Consolidated Statements of Cash Flows only include capital expenditures funded with cash payments during the period.

The Company’s capital spending increased slightly for the six months ended June 30, 2013, due to higher expenditures for domestic onshore plants and gathering systems. In March 2013, WES acquired a 33.75% interest in gas-gathering systems located in the Marcellus shale in north-central Pennsylvania from a third party for $135 million. This increase was offset by lower exploration drilling in East and West Africa, and lower construction costs to Anadarko related to the development of the Lucius project located in the Gulf of Mexico as a result of the carried-interest arrangement discussed below.

In the second quarter of 2013, the Company entered into a carried-interest arrangement that requires a third-party partner to fund $860 million of Anadarko’s capital costs to earn a 12.75% working interest in the Heidelberg development, located in the Gulf of Mexico. The third-party funding is expected to cover nearly all of Anadarko’s expected future capital costs through first production, which is expected to occur by mid-2016. At June 30, 2013, $20 million of the total $860 million obligation had been funded.

In the third quarter of 2012, the Company entered into a carried-interest arrangement that requires a third-party partner to fund $556 million of Anadarko’s capital costs to earn a 7.2% working interest in the Lucius development, located in the Gulf of Mexico. The amount of the carry obligation represents 100% of the Company’s expected capital costs through first production. The funding obligation is expected to be complete by mid-2014. At June 30, 2013, $286 million of the total $556 million obligation had been funded.

In the first quarter of 2011, the Company entered into a carried-interest arrangement that requires a third-party partner to fund approximately $1.6 billion of Anadarko’s capital costs in the Eagleford shale, located in South Texas, to earn a one-third interest in Anadarko’s Eagleford shale assets. The carry was fully funded in June 2013.

Investments During the six months ended June 30, 2013, the Company made capital contributions of $235 million to equity subsidiaries.

Debt Retirements and Repayments During the six months ended June 30, 2013, WES repaid $245 million of borrowings under its RCF with proceeds from its public offering of common units, as discussed in Sources of Cash.

Pension and Other Postretirement Contributions During the six months ended June 30, 2013, the Company made contributions of $47 million to its funded pension plans, $2 million to its unfunded pension plans, and $6 million to its unfunded other postretirement benefit plans. During the remainder of 2013, the Company expects to contribute $50 million to its funded pension plans, $32 million to its unfunded pension plans, and $10 million to its unfunded other postretirement benefit plans.

Common Stock Dividends and Distributions to Noncontrolling Interest Owners Anadarko paid dividends to its common stockholders of $92 million during the six months ended June 30, 2013, and $91 million during the six months ended June 30, 2012 (nine cents per share in each quarterly period). Anadarko has paid a dividend to its common stockholders on a quarterly basis since becoming an independent public company in 1986. The amount of future dividends paid to Anadarko common stockholders will be determined by the Board of Directors on a quarterly basis and will depend on earnings, financial condition, capital requirements, the effect a dividend payment would have on the Company’s compliance with relevant financial covenants, and other factors.

WES distributed to its unitholders, other than Anadarko and WGP, an aggregate of $59 million during the six months ended June 30, 2013, and $45 million during the six months ended June 30, 2012. WES has made quarterly distributions to its unitholders since its initial public offering in the second quarter of 2008, and has increased its distribution from $0.30 per common unit for the third quarter of 2008 to $0.56 per common unit for the second quarter of 2013 (to be paid in August 2013).

WGP distributed to its unitholders, other than Anadarko, an aggregate of $4 million during the six months ended June 30, 2013. WGP has declared a cash distribution of $0.19750 per unit for the second quarter of 2013 (to be paid in August 2013).

Outlook

The Company is committed to the execution of its worldwide exploration, appraisal, and development programs. The Company estimates a 2013 capital spending range of $7.8 billion to $8.2 billion. This amount includes $550 million to $600 million for WES capital expenditures, excluding WES acquisitions. The Company plans to allocate approximately 70% of its 2013 capital spending to development activities, 20% to exploration activities, and 10% to gas-gathering and processing activities and other business activities. The Company expects its 2013 capital spending by area to be approximately 60% for the U.S. onshore area and Alaska, 15% for the Gulf of Mexico, 15% for International, and 10% for midstream and other.

Anadarko believes that its cash on hand and expected level of operating cash flows will be sufficient to fund the Company’s projected operational and capital programs for 2013 and continue to meet its other obligations. The Company’s cash on hand is available for use and could be supplemented, as needed, with available borrowing capacity under the $5.0 billion Facility. The Company currently does not consider European sovereign debt events to pose significant risk to the Company’s ability to access available borrowing capacity under the $5.0 billion Facility. The Company may also enter into carried-interest arrangements with third parties to fund certain capital expenditures and execute asset divestitures to supplement cash flow.

The Company continuously monitors its liquidity needs, coordinates its capital expenditure program with its expected cash flows and projected debt-repayment schedule, and evaluates available funding alternatives in light of current and expected conditions. In order to reduce commodity-price risk and increase the predictability of 2013 cash flows, Anadarko entered into strategic derivative positions, which cover approximately 62% of its remaining 2013 anticipated natural-gas sales volumes and 49% of its remaining 2013 anticipated crude-oil sales volumes. In addition, the Company has derivative positions in place for 2014. In July 2013, the Company entered into 2013 fixed-price swaps for 14 MBbls/d, at an average price of $104.36 per barrel. See Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Obligations and Commitments

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The Company’s primary market risks are attributable to fluctuations in energy prices and interest rates. In addition, foreign-currency exchange-rate risk exists due to anticipated foreign-currency denominated payments and receipts. These risks can affect revenues and cash flow from operating, investing, and financing activities. The Company’s risk-management policies provide for the use of derivative instruments to manage these risks. The types of commodity derivative instruments used by the Company include futures, swaps, options, and fixed-price physical-delivery contracts. The volume of commodity derivatives entered into by the Company is governed by risk-management policies and may vary from year to year. Both exchange and over-the-counter traded commodity derivative instruments may be subject to margin deposit requirements, and the Company may be required from time to time to deposit cash or provide letters of credit with exchange brokers or counterparties in order to satisfy these margin requirements. For additional information related to the Company’s derivative and financial instruments, see Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

COMMODITY-PRICE RISK The Company’s most significant market risk relates to prices for natural gas, crude oil, and NGLs. Management expects energy prices to remain volatile. As energy prices decline or rise significantly, revenues and cash flows are likewise affected. In addition, a non-cash write-down of the Company’s oil and gas properties or goodwill may be required if commodity prices experience a significant decline. Below is a sensitivity analysis for the Company’s commodity-price-related derivative instruments.

Derivative Instruments Held for Non-Trading Purposes At June 30, 2013, the Company had derivative instruments in place to reduce the price risk associated with future production of 730 Bcf of natural gas and 25 MMBbls of crude oil, with a net derivative asset position of $310 million. Based on actual derivative contractual volumes, a 10% increase in underlying commodity prices would reduce the fair value of these derivatives by $428 million, while a 10% decrease in underlying commodity prices would increase the fair value of these derivatives by $439 million. However, any realized derivative gain or loss would be substantially offset by the realized sales value of production covered by the derivative instruments.

Derivative Instruments Held for Trading Purposes At June 30, 2013, the Company had a net derivative asset position of $12 million (unrealized gains of $26 million and unrealized losses of $14 million) on derivative instruments entered into for trading purposes. Based on actual derivative contractual volumes, a 10% increase or decrease in underlying commodity prices would not materially impact the Company’s gains or losses on these derivative instruments.

INTEREST-RATE RISK Any borrowings under the $5.0 billion Facility and the WES RCF are subject to variable interest rates. The balance of Anadarko’s long-term debt on the Company’s Consolidated Balance Sheet is subject to fixed interest rates. The Company’s $2.9 billion of London Interbank Offered Rate (LIBOR) based obligations, which are presented on the Company’s Consolidated Balance Sheets net of preferred investments in two non-controlled entities, give rise to minimal net interest-rate risk because coupons on the related preferred investments are also LIBOR-based. A 10% increase in LIBOR would not materially impact the Company’s interest cost on outstanding debt, but would affect fair value of outstanding debt.

At June 30, 2013, the Company had a net derivative liability position of $840 million related to interest-rate swaps. A 10% increase or decrease in interest rates would increase or decrease the aggregate fair value of outstanding interest-rate swap agreements by approximately $133 million. However, any change in the interest-rate derivative gain or loss would be substantially offset by borrowing costs associated with any future debt issuances. For a summary of the Company’s open interest-rate derivative positions, see Note 7—Derivative Instruments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

FOREIGN-CURRENCY EXCHANGE-RATE RISK Anadarko’s operating revenues are primarily realized in U.S. dollars, and the predominant portion of Anadarko’s capital and operating expenditures are U.S.-dollar-denominated. Exposure to foreign-currency risk generally arises in connection with project-specific contractual arrangements and other commitments. Near-term foreign-currency-denominated expenditures are primarily in euros, Brazilian reais, British pounds sterling, and Mozambican meticais. Management periodically enters into various risk-management transactions to mitigate a portion of its exposure to foreign-currency exchange-rate risk.

The Company has risk related to exchange-rate changes applicable to cash held in escrow pending final determination of the Company’s Brazilian tax liability for its 2008 divestiture of the Peregrino field offshore Brazil. At June 30, 2013, cash of $152 million was held in escrow. A 10% increase or decrease in the foreign-currency exchange rate would not materially impact the Company’s gain or loss related to foreign currency.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Anadarko’s Chief Executive Officer and Chief Financial Officer performed an evaluation of the Company’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934. The Company’s disclosure controls and procedures are designed to ensure that information required to be disclosed by the Company in reports it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission, and to ensure that the information required to be disclosed by the Company in reports that it files under the Securities Exchange Act of 1934 is accumulated and communicated to the Company’s management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that the Company’s disclosure controls and procedures are effective as of June 30, 2013.

Changes in Internal Control over Financial Reporting

There were no changes in Anadarko’s internal control over financial reporting during the second quarter of 2013 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

GENERAL The Company is a defendant in a number of lawsuits and is involved in governmental proceedings and regulatory controls arising in the ordinary course of business, including, but not limited to, personal injury claims; title disputes; tax disputes; royalty claims; contract claims; contamination claims relating to oil and gas production, transportation, and processing; and environmental claims, including claims involving assets owned by acquired companies. Anadarko is also subject to various environmental-remediation and reclamation obligations arising from federal, state, and local laws and regulations. While the ultimate outcome and impact on the Company cannot be predicted with certainty, after consideration of recorded expense and liability accruals, management believes that the resolution of pending proceedings will not have a material adverse effect on the Company’s consolidated financial position, results of operations, or cash flows.

See Note 12—Contingencies in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q, which is incorporated herein by reference, for material developments with respect to matters previously reported in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, and material matters that have arisen since the filing of such report.

Item 1A. Risk Factors

Consider carefully the risk factor included below, as well as those under the caption “Risk Factors” under Part I, Item 1A in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, together with all of the other information included in this Form 10-Q; in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012; and in the Company’s other public filings, press releases, and public discussions with Company management.

We are, and in the future may become, involved in legal proceedings related to Tronox and, as a result, may incur substantial costs in connection with those proceedings.

In January 2009, Tronox Incorporated (Tronox), a former subsidiary of Kerr-McGee Corporation (Kerr-McGee), which is a current subsidiary of Anadarko, and certain of Tronox’s subsidiaries filed voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Southern District of New York. Subsequently, in May 2009, Tronox and certain of its affiliates filed a lawsuit against Anadarko and Kerr-McGee asserting a number of claims, including claims for actual and constructive fraudulent conveyance. Tronox alleges, among other things, that it was insolvent or undercapitalized at the time it was spun off from Kerr-McGee and seeks, among other things, to recover damages, including interest, in excess of $18.9 billion from Kerr-McGee and Anadarko, as well as litigation fees and costs. For a description of the updates to this litigation since the description thereof included in Note 17—Contingencies—Tronox Litigation in the Notes to Consolidated Financial Statements included in Part II, Item 8 of the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, see Note 12—Contingencies—Tronox Litigation in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q. An adverse resolution of any proceedings related to Tronox could subject us to significant monetary damages and other penalties, which could have a material adverse effect on our business, prospects, results of operations, financial condition, and liquidity.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The following sets forth information with respect to repurchases by the Company of its shares of common stock during the second quarter of 2013.



Period	Total number of shares purchased ⁽¹⁾	Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs	Approximate dollar value of shares that may yet be purchased under the plans or programs
April 1-30	567	$	86.10	—
May 1-31	3,699	$	86.99	—
June 1-30	28,200	$	87.52	—
Second-Quarter 2013	32,466	$	87.43	—	$	—

____________________________________________________________


⁽¹⁾	During the second quarter of 2013, all purchased shares related to stock received by the Company for the payment of withholding taxes due on employee stock plan share issuances.

Item 6. Exhibits

Exhibits not incorporated by reference to a prior filing are designated by an asterisk (*) and are filed herewith or double asterisk (**) and are furnished herewith; all exhibits not so designated are incorporated herein by reference to a prior filing as indicated.



Exhibit Number			Description	File Number

	3	(i)	Restated Certificate of Incorporation of Anadarko Petroleum Corporation, dated May 21, 2009, filed as exhibit 3.3 to Form 8-K filed on May 22, 2009	1-8968

		(ii)	By-Laws of Anadarko Petroleum Corporation, amended and restated as of May 15, 2012, filed as exhibit 3.1 to Form 8-K filed on May 15, 2012	1-8968

*	10	(i)	Form of Award Letter for Anadarko Petroleum Corporation 2008 Director Compensation Plan (2013)

*	31	(i)	Rule 13a-14(a)/15d-14(a) Certification—Chief Executive Officer

*	31	(ii)	Rule 13a-14(a)/15d-14(a) Certification—Chief Financial Officer

**	32		Section 1350 Certifications

*	101	.INS	XBRL Instance Document

*	101	.SCH	XBRL Schema Document

*	101	.CAL	XBRL Calculation Linkbase Document

*	101	.DEF	XBRL Definition Linkbase Document

*	101	.LAB	XBRL Label Linkbase Document

*	101	.PRE	XBRL Presentation Linkbase Document

SIGNATURES

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



		ANADARKO PETROLEUM CORPORATION (Registrant)

July 29, 2013	By:	/s/ ROBERT G. GWIN
		Robert G. Gwin Executive Vice President, Finance and Chief Financial Officer