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Document and Entity Information	9 Months Ended
Document and Entity Information	Sep. 30, 2012 shares
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Trading Symbol	HES
Entity Registrant Name	HESS CORP
Entity Central Index Key	0000004447
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	341,547,049

CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011
CURRENT ASSETS
Cash and cash equivalents	$ 528	$ 351
Accounts receivable
Trade	3,908	4,761
Other	336	250
Inventories	1,218	1,423
Other current assets	2,167	1,554
Total current assets	8,157	8,339
INVESTMENTS IN AFFILIATES	401	384
PROPERTY, PLANT AND EQUIPMENT
Total - at cost	44,266	39,710
Less: Reserves for depreciation, depletion, amortization and lease impairment	16,122	14,998
Property, plant and equipment - net	28,144	24,712
Goodwill	2,208	2,305
DEFERRED INCOME TAXES	2,872	2,941
OTHER ASSETS	430	455
TOTAL ASSETS	42,212	39,136
CURRENT LIABILITIES
Accounts payable	2,543	3,712
Accrued liabilities	3,905	3,524
Taxes payable	779	812
Short-term debt and current maturities of long-term debt	621	52
Total current liabilities	7,848	8,100
LONG-TERM DEBT	7,220	6,005
DEFERRED INCOME TAXES	2,696	2,843
ASSET RETIREMENT OBLIGATIONS	2,295	1,844
OTHER LIABILITIES AND DEFERRED CREDITS	1,501	1,752
Total liabilities	21,560	20,544
Hess Corporation Stockholders' Equity
Common stock, par value $1.00 Authorized - 600,000,000 shares Issued - 341,547,049 shares at September 30, 2012; 339,975,610 shares at December 31, 2011	342	340
Capital in excess of par value	3,498	3,417
Retained earnings	17,377	15,826
Accumulated other comprehensive income (loss)	(675)	(1,067)
Total Hess Corporation stockholders' equity	20,542	18,516
Noncontrolling interests	110	76
Total equity	20,652	18,592
TOTAL LIABILITIES AND EQUITY	$ 42,212	$ 39,136

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Sep. 30, 2012	Dec. 31, 2011
Common stock, par value	$ 1.00	$ 1.00
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	341,547,049	339,975,610

STATEMENT OF CONSOLIDATED INCOME - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
REVENUES AND NON-OPERATING INCOME
Sales (excluding excise taxes) and other operating revenues	$ 9,194	$ 8,665	$ 28,180	$ 28,733
Income (loss) from equity investment in HOVENSA L.L.C.		(36)		(133)
Gains on asset sales	376	103	412	446
Other, net	49	(6)	83	1
Total revenues and non-operating income	9,619	8,726	28,675	29,047
COSTS AND EXPENSES
Cost of products sold (excluding items shown separately below)	6,019	6,181	18,667	20,062
Production expenses	712	609	2,062	1,739
Marketing expenses	259	266	775	796
Exploration expenses, including dry holes and lease impairment	259	199	708	769
Other operating expenses	41	43	123	127
General and administrative expenses	167	177	506	515
Interest expense	104	94	313	290
Depreciation, depletion and amortization	748	586	2,198	1,732
Asset impairments	208	358	267	358
Total costs and expenses	8,517	8,513	25,619	26,388
INCOME BEFORE INCOME TAXES	1,102	213	3,056	2,659
Provision (benefit) for income taxes	510	(54)	1,369	849
NET INCOME	592	267	1,687	1,810
Less: Net income (loss) attributable to noncontrolling interests	35	(31)	36	(24)
NET INCOME ATTRIBUTABLE TO HESS CORPORATION	$ 557	$ 298	$ 1,651	$ 1,834
BASIC NET INCOME PER SHARE	$ 1.65	$ 0.89	$ 4.88	$ 5.45
DILUTED NET INCOME PER SHARE	$ 1.64	$ 0.88	$ 4.85	$ 5.40
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING (DILUTED)	339,950	340,222	340,270	339,838
COMMON STOCK DIVIDENDS PER SHARE	$ 0.10	$ 0.10	$ 0.30	$ 0.30

STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Net income	$ 592	$ 267	$ 1,687	$ 1,810
Derivatives designated as cash flow hedges
Effect of hedge losses reclassified to income	14	169	480	512
Income taxes on effect of hedge losses reclassified to income	(3)	(63)	(179)	(191)
Net effect of hedge losses reclassified to income	11	106	301	321
Change in fair value of cash flow hedges	(130)	(3)	(166)	(13)
Income taxes on change in fair value of cash flow hedges	52	1	65	5
Net change in fair value of cash flow hedges	(78)	(2)	(101)	(8)
Change in deferred gains (losses) on cash flow hedges, after-tax	(67)	104	200	313
Pension and other postretirement plans
Change in plan liabilities	21	13	64	36
Income taxes on change in plan liabilities	(8)	(5)	(24)	(14)
Change in plan liabilities, after-tax	13	8	40	22
Foreign currency translation adjustment and other	161	(319)	153	(40)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	107	(207)	393	295
COMPREHENSIVE INCOME	699	60	2,080	2,105
Less: Comprehensive income (loss) attributable to noncontrolling interests	38	(33)	37	(21)
COMPREHENSIVE INCOME ATTRIBUTABLE TO HESS CORPORATION	$ 661	$ 93	$ 2,043	$ 2,126

STATEMENT OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,687	$ 1,810
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	2,198	1,732
Asset impairments	267	358
Exploratory dry hole costs and lease impairment	373	434
Provision (benefit) for deferred income taxes	(47)	(224)
(Income) loss from equity investment in HOVENSA L.L.C.		133
Gains on asset sales	(412)	(446)
Stock compensation expense	73	77
Changes in operating assets and liabilities and other	(49)	(28)
Net cash provided by operating activities	4,090	3,846
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(6,016)	(4,891)
Proceeds from asset sales	656	490
Other, net	(22)	(74)
Net cash used in investing activities	(5,382)	(4,475)
CASH FLOWS FROM FINANCING ACTIVITIES
Net borrowings of debt with maturities of 90 days or less	1,583
Debt with maturities of greater than 90 days
Borrowings	448	14
Repayments	(432)	(50)
Cash dividends paid	(136)	(136)
Other, net	6	20
Net cash provided by (used in) financing activities	1,469	(152)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	177	(781)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	351	1,608
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$ 528	$ 827

STATEMENT OF CONSOLIDATED EQUITY - USD ($) $ in Millions	Total	Common Stock [Member]	Capital in Excess of Par Value [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Total Hess Stockholder's Equity [Member]	Noncontrolling Interests [Member]
Beginning balance at Dec. 31, 2010	$ 16,809	$ 338	$ 3,256	$ 14,254	$ (1,159)	$ 16,689	$ 120
Net income	1,810			1,834		1,834	(24)
Other comprehensive income (loss)	295				292	292	3
Comprehensive income (loss)	2,105					2,126	(21)
Activity related to restricted common stock awards, net	39	1	38			39
Employee stock options, including income tax benefits	105	1	104			105
Cash dividends declared	(102)			(102)		(102)
Noncontrolling interests, net	(42)		(29)	5		(24)	(18)
Ending balance at Sep. 30, 2011	18,914	340	3,369	15,991	(867)	18,833	81
Beginning balance at Dec. 31, 2011	18,592	340	3,417	15,826	(1,067)	18,516	76
Net income	1,687			1,651		1,651	36
Other comprehensive income (loss)	393				392	392	1
Comprehensive income (loss)	2,080					2,043	37
Activity related to restricted common stock awards, net	42	2	40			42
Employee stock options, including income tax benefits	36		36			36
Performance share units	5		5			5
Cash dividends declared	(102)			(102)		(102)
Noncontrolling interests, net	(1)			2		2	(3)
Ending balance at Sep. 30, 2012	$ 20,652	$ 342	$ 3,498	$ 17,377	$ (675)	$ 20,542	$ 110

- Definition

The change in equity [net assets] of a business enterprise during a period from transactions and other events and circumstances from non-owner sources which are attributable to the economic entity, including both controlling (parent) and noncontrolling interests. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners, including any and all transactions which are directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent.

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- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

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+ Details

- Definition

Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity.

+ References + Details

Basis of Presentation

9 Months Ended

Sep. 30, 2012

Basis of Presentation

1. Basis of Presentation

The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of Hess Corporation’s (the Corporation) consolidated financial position at September 30, 2012 and December 31, 2011 and the consolidated results of operations for the three and nine month periods ended September 30, 2012 and 2011 and the consolidated cash flows for the nine month periods ended September 30, 2012 and 2011. The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year.

The financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (SEC) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by U.S. generally accepted accounting principles (GAAP) have been condensed or omitted from these interim financial statements. These statements, therefore, should be read in conjunction with the consolidated financial statements and related notes included in the Corporation’s Form 10-K for the year ended December 31, 2011. Certain information in the financial statements and notes has been reclassified to conform to the current period presentation.

Effective January 1, 2012, the Corporation adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income, which requires comprehensive income to be presented either at the end of the income statement or as a separate statement immediately following the income statement. The Corporation elected to adopt the separate statement method.

Effective January 1, 2012, the Corporation adopted FASB ASU 2011-04, Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRS. For the Corporation, this standard requires additional disclosures related to fair value measurements, which are included in Note 15, Risk Management and Trading Activities.

- Definition

The entire disclosure for organization, consolidation and basis of presentation of financial statements disclosure.

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+ Details

Dispositions

9 Months Ended

Sep. 30, 2012

Dispositions

2. Dispositions

In September 2012, the Corporation completed the sale of its interests in the Schiehallion Field (Hess 16%) in the United Kingdom North Sea, its share of the associated floating production, storage and offloading vessel, and the West of Shetland pipeline system for cash proceeds of $524 million, after normal post-closing adjustments. The transaction resulted in a pre-tax gain of $376 million ($349 million after income taxes), after deducting the net book value of assets including allocated goodwill of $27 million. The Schiehallion Field was producing at a net rate of approximately 9,000 barrels of oil equivalent per day (boepd) at the time of sale.

In January 2012, the Corporation completed the sale of its interest in the Snohvit Field (Snohvit) (Hess 3%), offshore Norway, for cash proceeds of $132 million, after normal post-closing adjustments. The transaction resulted in a gain of $36 million, after deducting the net book value of assets including allocated goodwill of $14 million. Snohvit was producing at a net rate of approximately 3,000 boepd at the time of sale.

In August 2011, the Corporation completed the sale of its interests in the Snorre Field (Hess 1%), offshore Norway and the Cook Field (Hess 28%) in the United Kingdom North Sea for cash proceeds of $131 million, after normal post-closing adjustments. These disposals resulted in non-taxable gains totaling $103 million. These assets were producing at a combined net rate of approximately 2,500 boepd at the time of sale.

In February 2011, the Corporation completed the sale of its interests in certain natural gas producing assets in the United Kingdom North Sea for cash proceeds of $359 million, after post-closing adjustments. These disposals resulted in pre-tax gains totaling $343 million ($310 million after income taxes). These assets had a net productive capacity of approximately 15,000 boepd at the time of sale.

Inventories

9 Months Ended

Sep. 30, 2012

Inventories

3. Inventories

Inventories were as follows:


	September 30,			December 31,
	2012			2011
	(In millions)
Crude oil and other charge stocks	$	533		$	451
Refined petroleum products and natural gas		1,367			1,762
Less: LIFO adjustment		(1,209	)		(1,276	)

		691			937
Merchandise, materials and supplies		527			486

Total inventories	$	1,218		$	1,423

Property, Plant and Equipment

9 Months Ended

Sep. 30, 2012

Property, Plant and Equipment

4. Property, Plant and Equipment

Assets Held for Sale: In February 2012, the Corporation reached an agreement to sell its interest in the Bittern Field (Hess 28%) in the United Kingdom North Sea. See Note 16, Subsequent Events. In September 2012, the Corporation reached an agreement to sell its assets in Azerbaijan consisting of its interests in the Azeri-Chirag-Guneshli (ACG) fields (Hess 3%) and the associated Baku-Tbilisi-Ceyhan (BTC) pipeline (Hess 2%) for $1 billion, before normal post-closing adjustments. This transaction is subject to various government approvals. In October 2012, the Corporation also announced that it had reached an agreement to sell its interests in the Beryl fields (Hess 22%) in the United Kingdom North Sea for $525 million, before normal post-closing adjustments. This transaction is subject to regulatory approval.

At September 30, 2012, long-term assets totaling $1,179 million, primarily comprising the net property, plant and equipment balances and allocated goodwill of $112 million, have been classified as held for sale and reported in Other current assets. In addition, related long-term asset retirement obligations and deferred income taxes totaling $618 million were reported in Accrued liabilities.

Capitalized Exploratory Well Costs: The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves for the nine months ended September 30, 2012 (in millions):


Balance at January 1	$	2,022
Additions to capitalized exploratory well costs pending the determination of proved reserves		406
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(30	)
Capitalized exploratory well costs charged to expense		(124	)

Balance at end of period	$	2,274

Capitalized exploratory well costs charged to expense in the preceding table exclude $86 million of exploratory well costs which were incurred and subsequently expensed in 2012. Capitalized exploratory well costs greater than one year old after completion of drilling were $1,770 million at September 30, 2012. Approximately 37% of the capitalized well costs in excess of one year relates to the Pony discovery on Green Canyon Block 468 in the deepwater Gulf of Mexico, where development planning is progressing. In August 2012, the Corporation signed an exchange agreement with the partners on the adjacent Block 512, which contains the Knotty Head discovery. Under this agreement, the Corporation was appointed operator and has a 20% working interest in the blocks, now collectively referred to as Stampede. Approximately 37% relates to Block WA-390-P, offshore Western Australia, where development planning and commercial activities, including negotiations with potential liquefaction partners, are ongoing. Approximately 15% relates to Area 54, offshore Libya, where force majeure was withdrawn in March 2012 and the Corporation is pursuing commercial options. Approximately 7% relates to offshore Ghana where further drilling is ongoing. The remainder of the capitalized well costs in excess of one year relates to projects where further drilling is planned or development planning and other assessment activities are ongoing to determine the economic and operating viability of the projects.

Asset Impairments

9 Months Ended

Sep. 30, 2012

Asset Impairments

5. Asset Impairments

In the third quarter of 2012, the Corporation recorded impairment charges of $208 million ($116 million after income taxes) due to increases in the Corporation’s estimated abandonment liabilities for non-producing properties, which resulted in the book value of the properties exceeding their fair value. See Note 7, Asset Retirement Obligations. In the second quarter of 2012, the Corporation recorded a charge of $59 million ($36 million after-tax) to reduce the carrying value of certain properties in the Eagle Ford shale in Texas to their fair value (a Level 3 fair value measurement). In the third quarter of 2011, the Corporation recorded impairment charges of $358 million ($140 million after income taxes) related to increases in the Corporation’s estimated abandonment liabilities primarily for non-producing properties. For both years, these asset impairments related to the Exploration and Production (E&P) segment.

Libyan Operations

9 Months Ended

Sep. 30, 2012

Libyan Operations

6. Libyan Operations

In response to civil unrest in Libya and the resulting imposition of sanctions, production at the Waha fields was suspended in the first quarter of 2011. During the fourth quarter of 2011, the sanctions were lifted, force majeure was withdrawn and production resumed. The Corporation’s Libyan production averaged 23,000 boped in the third quarter of 2012. The force majeure covering the Corporation’s offshore exploration interests was withdrawn in March 2012.

Asset Retirement Obligations

9 Months Ended

Sep. 30, 2012

Asset Retirement Obligations

7. Asset Retirement Obligations

The following table describes changes to the Corporation’s asset retirement obligations:


	September 30,			December 31,
	2012			2011
	(In millions)
Asset retirement obligations at beginning of period	$	2,071		$	1,358
Liabilities incurred		229			25
Liabilities settled or disposed of		(274	)		(334	)
Accretion expense		101			96
Revisions of estimated liabilities		505			947
Foreign currency translation		42			(21	)

Asset retirement obligations at end of period		2,674			2,071
Less: current obligations		379			227

Long-term obligations at end of period	$	2,295		$	1,844

The revisions in 2012 reflect overall increases in estimated abandonment obligations resulting from changes in the expected scope of operations, increases in the time expected to complete dismantlement activities and updates to service rates.

HOVENSA L.L.C. Joint Venture

9 Months Ended

Sep. 30, 2012

HOVENSA L.L.C. Joint Venture

8. HOVENSA L.L.C. Joint Venture

In January 2012, HOVENSA L.L.C. (HOVENSA) announced a decision to shut down its refinery in St. Croix, U.S. Virgin Islands. As a result, the Corporation recorded an accrued liability of $487 million at December 31, 2011 for its share of future funding commitments for costs to shut down HOVENSA’s refinery. The Corporation and its partner fully funded their estimated commitments in the first quarter of 2012.

- Definition

The entire disclosure for equity method investments and joint ventures. Equity method investments are investments that give the investor the ability to exercise significant influence over the operating and financial policies of an investee. Joint ventures are entities owned and operated by a small group of businesses as a separate and specific business or project for the mutual benefit of the members of the group.

+ References + Details

Debt

9 Months Ended

Sep. 30, 2012

Debt

9. Debt

In the first nine months of 2012, the Corporation borrowed a net total of $1,599 million which consisted of borrowings of $1 billion from its syndicated revolving credit facility, $583 million from its short-term credit facilities and $68 million from its asset-backed credit facility, partially offset by net repayments of other debt of $52 million. At September 30, 2012, the Corporation classified $521 million of outstanding borrowings under short-term and asset-backed credit facilities as long-term, based on availability under its $4 billion syndicated revolving credit facility.

During 2012, the Corporation recorded a net increase of $138 million in long-term debt principally related to progress on construction of a leased floating production system to be used at the Tubular Bells project. In addition, during the third quarter, the Corporation assumed $47 million of capital lease obligations applicable to retail gasoline stations.

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References + Details

Foreign Currency

9 Months Ended

Sep. 30, 2012

Foreign Currency

10. Foreign Currency

Pre-tax foreign currency gains (losses) amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Pre-tax foreign currency gains (losses)	$	17	$	(9	)	$	25	$	(18	)

- Definition

The entire disclosure for foreign currency transactions and translation. This may include description of foreign currency transactions, foreign currency gains and losses, explanation of change in cumulative translation adjustment, description of effect of subsequent foreign currency exchange rate change, cumulative translation adjustment movement, foreign currency translation adjustment by component movement, translation adjustment for net investment hedge movement, adjustment for long-term intercompany transactions, schedule of long-term intercompany balances and any other foreign currency transactions and translation related items.

+ References

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-Publisher FASB
-Name Accounting Standards Codification
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 52
-Paragraph 30, 31, 32
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Retirement Plans

9 Months Ended

Sep. 30, 2012

Retirement Plans

11. Retirement Plans

Components of net periodic pension cost consisted of the following:


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2012			2011			2012			2011
	(In millions)
Service cost	$	19		$	15		$	55		$	43
Interest cost		22			23			66			67
Expected return on plan assets		(29	)		(28	)		(87	)		(82	)
Amortization of net loss		21			13			63			35

Pension expense	$	33		$	23		$	97		$	63

For the full year of 2012, the Corporation expects to contribute approximately $150 million to its funded pension plans. Through September 30, 2012, the Corporation contributed $116 million of this amount.

- Definition

The entire disclosure for pension and other postretirement benefits.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
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Reference 13: http://www.xbrl.org/2003/role/presentationRef
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Income Taxes

9 Months Ended

Sep. 30, 2012

Income Taxes

12. Income Taxes

The provision (benefit) for income taxes consisted of the following:


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2012			2011			2012			2011
	(In millions)
Current	$	509		$	169		$	1,416		$	1,073
Deferred		(114	)		(252	)		(162	)		(253	)
Adjustment to deferred tax liabilities for foreign income tax rate change (*)		115			29			115			29

Total provision (benefit) for income taxes	$	510		$	(54	)	$	1,369		$	849

(*)

The 2012 adjustment represents the effect of the United Kingdom (U.K.) supplemental income tax rate change to 20% from 32% on dismantlement expenditures in July 2012. The 2011 adjustment represents the July 2011 increase in the supplementary tax rate on petroleum operations to 32% from 20% in the U.K.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Weighted Average Common Shares

9 Months Ended

Sep. 30, 2012

Weighted Average Common Shares

13. Weighted Average Common Shares

The weighted average number of common shares used in the basic and diluted earnings per share computations is as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2012		2011		2012		2011
	(In thousands)
Common shares—basic		338,570		337,380		338,325		336,721
Effect of dilutive securities
Restricted common stock		963		1,268		1,029		1,372
Stock options		417		1,574		916		1,745

Common shares—diluted		339,950		340,222		340,270		339,838

In March 2012, the Corporation changed the long-term incentive award program for its officers such that 50% of the shares awarded annually are performance share units (PSU’s) and the other 50% are in the form of restricted stock. The number of shares of common stock to be issued under the PSU agreement is based on a comparison of the Corporation’s total shareholder return (TSR) to the TSR of a predetermined group of fifteen peer companies over a three-year performance period ending December 31, 2014. Payouts of the 2012 performance share awards will range from 0% to 200% of the target awards based on the Corporation’s TSR ranking within the peer group. Dividend equivalents for the performance period will accrue on performance shares and will only be paid out on earned shares after the performance period.

The Corporation granted 1,561,300 shares of restricted stock and 420,628 PSU’s during the nine months ended September 30, 2012. For the nine months ended September 30, 2011, the Corporation granted 734,005 shares of restricted stock and 2,201,445 of stock options. The weighted average common shares used in the diluted earnings per share calculations exclude the effect of 11,519,000 and 8,810,000 of out-of-the-money stock options for the three and nine months ended September 30, 2012, respectively, and 412,977 of PSU’s for the three and nine months ended September 30, 2012. The calculations also exclude the effect of 4,180,000 and 2,763,000 of out-of-the-money stock options for the three and nine month periods ended September 30, 2011, respectively.

Segment Information

9 Months Ended

Sep. 30, 2012

Segment Information

14. Segment Information

The Corporation’s results by operating segment were as follows:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Operating revenues
Exploration and Production	$	3,072		$	2,217		$	9,292		$	7,760
Marketing and Refining		6,140			6,479			18,933			21,071
Less: Transfers between affiliates		(18	)		(31	)		(45	)		(98	)

Total (*)	$	9,194		$	8,665		$	28,180		$	28,733

Net income (loss) attributable to Hess Corporation
Exploration and Production	$	608		$	422		$	1,887		$	2,148
Marketing and Refining		53			(23	)		72			(23	)
Corporate, including interest		(104	)		(101	)		(308	)		(291	)

Total	$	557		$	298		$	1,651		$	1,834

(*)	Operating revenues exclude excise and similar taxes of approximately $640 million and $600 million for the three months ended September 30, 2012 and 2011, respectively, and $1,930 million and $1,750 million for the nine months ended September 30, 2012 and 2011, respectively.

Identifiable assets by operating segment were as follows:


	September 30, 2012		December 31, 2011
	(In millions)
Exploration and Production	$	36,031	$	32,323
Marketing and Refining		5,211		6,302
Corporate		970		511

Total	$	42,212	$	39,136

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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+ Details

Risk Management and Trading Activities

9 Months Ended

Sep. 30, 2012

Risk Management and Trading Activities

15. Risk Management and Trading Activities

In the normal course of its business, the Corporation is exposed to commodity risks related to changes in the prices of crude oil, natural gas, refined petroleum products and electricity, as well as to changes in interest rates and foreign currency values. In the disclosures that follow, risk management activities are referred to as energy marketing and corporate risk management activities. The Corporation also has trading operations, principally through a 50% voting interest in a consolidated partnership, that trades energy-related commodities, securities and derivatives. These activities are also exposed to commodity price risks primarily related to the prices of crude oil, natural gas, refined petroleum products and electricity.

The Corporation maintains a control environment under the direction of its chief risk officer and through its corporate risk policy, which the Corporation’s senior management has approved. Controls include volumetric, term and value at risk limits. The chief risk officer must approve the trading of new instruments or commodities. Risk limits are monitored and reported on a daily basis to business units and senior management. The Corporation’s risk management department also performs independent price verifications (IPV’s) of sources of fair values, validations of valuation models and analyzes changes in fair value measurements on a daily, monthly and/or quarterly basis. These controls apply to all of the Corporation’s risk management and trading activities, including the consolidated trading partnership. The Corporation’s treasury department is responsible for administering foreign exchange rate and interest rate hedging programs using similar controls and processes, where applicable.

The Corporation’s risk management department, in performing the IPV procedures, utilizes independent sources and valuation models that are specific to the individual contracts and pricing locations to identify positions that require adjustments to better reflect the market. This review is performed quarterly and the results are presented to the chief risk officer and senior management. The IPV process considers the reliability of the pricing services through assessing the number of available quotes, the frequency at which data is available and, where appropriate, the comparability between pricing sources.

Following is a description of the Corporation’s activities that use derivatives as part of their operations and strategies. Derivatives include both financial instruments and forward purchase and sale contracts. Gross notional amounts of both long and short positions are presented in the volume tables below. These amounts include long and short positions that offset in closed positions and have not reached contractual maturity. Gross notional amounts do not quantify risk or represent assets or liabilities of the Corporation, but are used in the calculation of cash settlements under the contracts.

Energy Marketing Activities: In its energy marketing activities the Corporation sells refined petroleum products, natural gas and electricity principally to commercial and industrial businesses at fixed and floating prices for varying periods of time. Commodity contracts such as futures, forwards, swaps and options, together with physical assets such as storage and pipeline capacity, are used to obtain supply and reduce margin volatility or lower costs related to sales contracts with customers.

The table below shows the gross volume of the Corporation’s energy marketing commodity contracts outstanding:


	September 30, 2012		December 31, 2011
Crude oil and refined petroleum products (millions of barrels)		28		28
Natural gas (millions of mcf)		2,961		2,616
Electricity (millions of megawatt hours)		336		244

The changes in fair value of certain energy marketing commodity contracts that are not designated as hedges are recognized currently in earnings. Revenues from the sales contracts are recognized in Sales and other operating revenues in the Statement of Consolidated Income, while supply contract purchases and net settlements from financial derivatives related to these energy marketing activities are recognized in Cost of products sold in the Statement of Consolidated Income. Net realized and unrealized pre-tax gains on derivative contracts not designated as hedges amounted to $66 million and $8 million for the three months ended September 30, 2012 and 2011, respectively, and $145 million and $36 million for the nine months ended September 30, 2012 and 2011, respectively.

At September 30, 2012, a portion of energy marketing commodity contracts were designated as cash flow hedges to hedge the variability of expected future cash flows of forecasted supply transactions. The length of time over which the Corporation hedges exposure to variability in future cash flows is predominantly one year or less. For contracts outstanding at September 30, 2012, the maximum duration was approximately two years.

The Corporation records the effective portion of changes in the fair value of cash flow hedges as a component of Accumulated other comprehensive income (loss) in the Consolidated Balance Sheet and then reclassifies amounts to Cost of products sold in the Statement of Consolidated Income as the hedged transactions are recognized in earnings. At September 30, 2012, the after-tax deferred losses relating to energy marketing activities recorded in Accumulated other comprehensive income (loss) were $35 million ($64 million at December 31, 2011). The Corporation estimates that after-tax losses of approximately $22 million will be reclassified into earnings over the next twelve months. During the three months ended September 30, 2012 and 2011, the Corporation reclassified from Accumulated other comprehensive income (loss) an after-tax gain of $6 million and an after-tax loss of $24 million, respectively, and after-tax losses of $45 million and $77 million for the nine months ended September 30, 2012 and 2011, respectively.

The amounts of ineffectiveness recognized immediately in Cost of products sold were losses of approximately $1 million and $2 million for the three months ended September 30, 2012 and 2011, respectively, and $1 million and $4 million for the nine months ended September 30, 2012 and 2011, respectively. The pre-tax amount of deferred hedge losses is reflected in Accounts payable and the related income tax benefits are recorded as deferred income tax assets, which are included in Other current assets in the Consolidated Balance Sheet.

As a result of changes in the fair value of energy marketing cash flow hedge positions, after-tax deferred losses decreased by $11 million and increased by $4 million for the three months ended September 30, 2012 and 2011, respectively, and increased by $16 million and $1 million for the nine months ended September 30, 2012 and 2011, respectively.

Corporate Risk Management Activities: Corporate risk management activities include transactions designed to reduce risk in the selling prices of crude oil, refined petroleum products or natural gas produced by the Corporation or to reduce exposure to foreign currency or interest rate movements. Generally, futures, swaps or option strategies may be used to fix the forward selling price of a portion of the Corporation’s crude oil, refined petroleum products or natural gas production. Forward contracts may also be used to purchase certain currencies in which the Corporation does business with the intent of reducing exposure to foreign currency fluctuations. These forward contracts comprise various currencies including the British Pound and Thai Baht. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.

The table below shows the gross volume of the Corporate risk management derivative contracts outstanding:


	September 30, 2012		December 31, 2011
Commodity, primarily crude oil (millions of barrels)		21		51
Foreign exchange (millions of U.S. Dollars)	$	998	$	900
Interest rate swaps (millions of U.S. Dollars)	$	880	$	895

During 2008, the Corporation closed Brent crude oil cash flow hedges covering 24,000 barrels per day through 2012, by entering into offsetting contracts with the same counterparty. As a result, the valuation of those contracts is no longer subject to change due to price fluctuations. The deferred hedge losses as of the date that the hedges were closed are being recorded in earnings as the hedged transactions occur. For 2012, the Corporation has entered into Brent crude oil hedges using fixed-price swap contracts to hedge the variability of forecasted future cash flows from 120,000 barrels per day of crude oil sales volumes for the full year. The average price for these hedges is $107.70 per barrel.

Realized losses from E&P hedging activities reduced Sales and other operating revenues by $148 million and $131 million for the three months ended September 30, 2012 and 2011, respectively ($94 million and $82 million after-tax, respectively), and $533 million and $387 million for the nine months ended September 30, 2012 and 2011, respectively ($334 million and $244 million after-tax, respectively).

At September 30, 2012, the after-tax deferred losses in Accumulated other comprehensive income (loss) related to Brent crude oil hedges were $115 million ($286 million at December 31, 2011), which will be reclassified into earnings during the remainder of 2012 as the hedged crude oil sales are recognized. The amount of ineffectiveness from Brent crude oil hedges that was recognized immediately in Sales and other operating revenues was a loss of $2 million for the three months ended September 30, 2012 and $10 million for the nine months ended September 30, 2012.

At September 30, 2012, the Corporation had interest rate swaps with a gross notional amount of $880 million, which were designated as fair value hedges. Changes in the fair value of interest rate swaps and the hedged fixed-rate debt are recorded in Interest expense in the Statement of Consolidated Income. The Corporation recorded an increase of $7 million and $42 million (excluding accrued interest) for the three months ended September 30, 2012 and 2011, respectively, and an increase of $17 million and $45 million (excluding accrued interest) for the nine months ended September 30, 2012 and 2011, respectively, in the fair value of interest rate swaps and a corresponding adjustment in the carrying value of the hedged fixed-rate debt.

Gains or losses on foreign exchange contracts that are not designated as hedges are recognized immediately in Other, net in Revenues and non-operating income in the Statement of Consolidated Income.

Net realized and unrealized pre-tax gains (losses) on derivative contracts used for Corporate risk management activities and not designated as hedges amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Commodity	$	—	$	—		$	—	$	1
Foreign exchange		31		(25	)		35		(12	)

Total	$	31	$	(25	)	$	35	$	(11	)

Trading Activities: Trading activities are conducted principally through a trading partnership in which the Corporation has a 50% voting interest. This consolidated entity intends to generate earnings through various strategies primarily using energy-related commodities, securities and derivatives. The Corporation also takes trading positions for its own account. The information that follows represents 100% of the trading partnership and the Corporation’s proprietary trading accounts.

The table below shows the gross volume of derivative contracts outstanding relating to trading activities:


	September 30, 2012		December 31, 2011
Commodity
Crude oil and refined petroleum products (millions of barrels)		1,662		2,169
Natural gas (millions of mcf)		4,109		4,203
Electricity (millions of megawatt hours)		84		304
Foreign exchange (millions of U.S. Dollars)	$	374	$	581
Other
Interest rate (millions of U.S. Dollars)	$	176	$	182
Equity securities (millions of shares)		12		16

Pre-tax unrealized and realized gains (losses) recorded in Sales and other operating revenues in the Statement of Consolidated Income from trading activities amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Commodity	$	75	$	(5	)	$	83	$	45
Foreign exchange		1		7			3		(1	)
Other		9		(52	)		8		(42	)

Total	$	85	$	(50	)	$	94	$	2

Fair Value Measurements: The table below reflects the gross and net fair values of the Corporation’s risk management and trading derivative instruments:


	Accounts Receivable			Accounts Payable
	(In millions)
September 30, 2012
Derivative contracts designated as hedging instruments
Commodity	$	61		$	(144	)
Interest rate and other		72			(2	)

Total derivative contracts designated as hedging instruments		133			(146	)


Derivative contracts not designated as hedging instruments (*)
Commodity		5,505			(5,499	)
Foreign exchange		26			(1	)
Other		16			(7	)

Total derivative contracts not designated as hedging instruments		5,547			(5,507	)


Gross fair value of derivative contracts		5,680			(5,653	)
Master netting arrangements		(4,666	)		4,666
Cash collateral (received) posted		(98	)		22

Net fair value of derivative contracts	$	916		$	(965	)

December 31, 2011
Derivative contracts designated as hedging instruments
Commodity	$	181		$	(216	)
Other		61			(3	)

Total derivative contracts designated as hedging instruments		242			(219	)


Derivative contracts not designated as hedging instruments (*)
Commodity		9,350			(9,823	)
Foreign exchange		6			(21	)
Other		12			(24	)

Total derivative contracts not designated as hedging instruments		9,368			(9,868	)


Gross fair value of derivative contracts		9,610			(10,087	)
Master netting arrangements		(7,962	)		7,962
Cash collateral (received) posted		(121	)		117

Net fair value of derivative contracts	$	1,527		$	(2,008	)

(*)

Includes trading derivatives and derivatives used for risk management.

The Corporation generally enters into master netting arrangements to mitigate counterparty credit risk. Master netting arrangements are standardized contracts that govern all specified transactions with the same counterparty and allow the Corporation to terminate all contracts upon occurrence of certain events, such as a counterparty’s default or bankruptcy. Where these arrangements provide the right of offset and the Corporation’s intent and practice is to offset amounts in the case of contract terminations, the Corporation’s policy is to record the fair value of derivative assets and liabilities on a net basis.

The Corporation determines fair value in accordance with the fair value measurements accounting standard (Accounting Standards Codification (Topic 820): Fair Value Measurements and Disclosures), which established a hierarchy that categorizes the sources of inputs, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using related market data (Level 3). Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2.

When Level 1 inputs are available within a particular market, those inputs are selected for determination of fair value over Level 2 or 3 inputs in the same market. To value derivatives that are characterized as Level 2 and 3, the Corporation uses observable inputs for similar instruments that are available from exchanges, pricing services or broker quotes. These observable inputs may be supplemented with other methods, including internal extrapolation or interpolation, that result in the most representative prices for instruments with similar characteristics. Multiple inputs may be used to measure fair value, however, the level of fair value for each physical derivative and financial asset or liability presented below is based on the lowest significant input level within this fair value hierarchy.

The following table provides the fair values for the Corporation’s net physical derivative and financial assets and (liabilities) that are based on this hierarchy:


	Level 1			Level 2			Level 3			Collateral and counterparty netting			Balance
	(In millions)
September 30, 2012
Assets
Derivative contracts
Commodity	$	168		$	668		$	240		$	(88	)	$	988
Foreign exchange		—			26			—			—			26
Interest rate and other		6			73			3			—			82
Collateral and counterparty netting		(2	)		(73	)		(7	)		(98	)		(180	)

Total derivative contracts		172			694			236			(186	)		916
Other assets measured at fair value on a recurring basis		1			3			—			—			4

Total assets measured at fair value on a recurring basis	$	173		$	697		$	236		$	(186	)	$	920


Liabilities
Derivative contracts
Commodity	$	(144	)	$	(884	)	$	(125	)	$	88		$	(1,065	)
Foreign exchange		—			(1	)		—			—			(1	)
Other		(1	)		(2	)		—			—			(3	)
Collateral and counterparty netting		2			73			7			22			104

Total derivative contracts		(143	)		(814	)		(118	)		110			(965	)
Other liabilities measured at fair value on a recurring basis		(31	)		(4	)		(1	)		—			(36	)

Total liabilities measured at fair value on a recurring basis	$	(174	)	$	(818	)	$	(119	)	$	110		$	(1,001	)

Other fair value measurement disclosures Long-term debt	$	—		$	(8,737	)	$	—		$	—		$	(8,737	)


December 31, 2011
Assets
Derivative contracts
Commodity	$	135		$	1,188		$	511		$	(67	)	$	1,767
Interest rate and other		—			66			—			—			66
Collateral and counterparty netting		(33	)		(148	)		(4	)		(121	)		(306	)

Total derivative contracts		102			1,106			507			(188	)		1,527
Other assets measured at fair value on a recurring basis		7			34			—			(2	)		39

Total assets measured at fair value on a recurring basis	$	109		$	1,140		$	507		$	(190	)	$	1,566

December 31, 2011
Liabilities
Derivative contracts
Commodity	$	(191	)	$	(1,501	)	$	(650	)	$	67		$	(2,275	)
Foreign exchange		—			(15	)		—			—			(15	)
Other		—			(18	)		(2	)		—			(20	)
Collateral and counterparty netting		33			148			4			117			302

Total derivative contracts		(158	)		(1,386	)		(648	)		184			(2,008	)
Other liabilities measured at fair value on a recurring basis		—			(52	)		(2	)		2			(52	)

Total liabilities measured at fair value on a recurring basis	$	(158	)	$	(1,438	)	$	(650	)	$	186		$	(2,060	)

Other fair value measurement disclosures Long-term debt	$	—		$	(7,317	)	$	—		$	—		$	(7,317	)

The following table provides changes in physical derivatives and financial assets and (liabilities) that are measured at fair value based on Level 3 inputs:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Balance at beginning of period	$	87		$	372		$	(143	)	$	412
Unrealized pre-tax gains (losses)
Included in earnings (a)		(26	)		(85	)		(72	)		19
Included in other comprehensive income (b)		—			13			43			30
Purchases (c)		14			415			244			1,932
Sales (c)		(9	)		(536	)		(266	)		(2,131	)
Settlements (d)		15			(162	)		232			(194	)
Transfers into Level 3		50			(222	)		100			(211	)
Transfers out of Level 3		(14	)		(39	)		(21	)		(101	)

Balance at end of period	$	117		$	(244	)	$	117		$	(244	)

(a)

The unrealized pre-tax gains (losses) included in earnings that are reflected in Sales and other operating revenues in the Statement of Consolidated Income amounted to $8 million and $(40) million for the three and nine months ended September 30, 2012, respectively. The unrealized pre-tax gains (losses) included in earnings that are reflected in Cost of products sold in the Statement of Consolidated Income amounted to $(34) million and $(32) million for the three and nine months ended September 30, 2012, respectively.

(b)

The unrealized pre-tax gains (losses) included in Other comprehensive income are reflected in the Change in fair value of cash flow hedges in the Statement of Consolidated Comprehensive Income.

(c)

Purchases and sales primarily represent option premiums paid or received, respectively, during the reporting period.

(d)

Settlements represent realized gains and (losses) on derivatives settled during the reporting period.

The following table provides net transfers into and out of each level of the fair value hierarchy:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Transfers into Level 1	$	85		$	(4	)	$	244		$	(12	)
Transfers out of Level 1		(38	)		39			210			318

	$	47		$	35		$	454		$	306


Transfers into Level 2	$	48		$	28		$	(245	)	$	34
Transfers out of Level 2		(131	)		198			(288	)		(28	)

	$	(83	)	$	226		$	(533	)	$	6


Transfers into Level 3	$	50		$	(222	)	$	100		$	(211	)
Transfers out of Level 3		(14	)		(39	)		(21	)		(101	)

	$	36		$	(261	)	$	79		$	(312	)

The Corporation’s policy is to recognize transfers in and transfers out as of the end of the reporting period. Transfers between levels result from the passage of time as contracts move closer to their maturities, fluctuations in the market liquidity for certain contracts and/or changes in the level of significance of fair value measurement inputs.

The significant unobservable inputs used in Level 3 fair value measurements for the Corporation’s physical commodity contracts and derivative instruments primarily include less liquid delivered locations for physical commodity contracts or volatility assumptions for out-of-the-money options. The following table provides information about the Corporation’s significant recurring unobservable inputs used in the Level 3 fair value measurements. Natural gas contracts are usually quoted and transacted using basis pricing relative to an active pricing location (e.g. Henry Hub) for which price inputs represent the approximate value of differences in geography and local market conditions. All other price inputs below represent full contract prices. Significant changes in any of the inputs below, independently or correlated, may result in a different fair value.


	Unit of Measurement	Range / Weighted Average
September 30, 2012
Assets
Commodity contracts with a fair value of $240 million Contract prices
Crude oil and refined petroleum products	$ / bbl	$	86.99 - 151.52 / 115.69
Electricity	$ / MWH	$	24.65 - 84.38 / 50.69

Basis prices
Natural gas	$ / MMBTU	$	(0.60) - 4.59 / 0.33

Contract volatilities
Crude oil and refined petroleum products	%		22.00 - 31.00 / 29.00
Natural gas	%		22.00 - 23.00 / 22.00
Electricity	%		18.00 - 31.00 / 26.00

September 30, 2012
Liabilities
Commodity contracts with a fair value of $125 million Contract prices
Crude oil and refined petroleum products	$ / bbl	$	86.98 - 156.53 / 116.25
Electricity	$ / MWH	$	24.65 - 84.38 / 51.09

Basis prices
Natural gas	$ / MMBTU	$	(0.55) - 4.55 / 0.86

Contract volatilities
Crude oil and refined petroleum products	%		28.00 - 31.00 / 30.00
Natural gas	%		22.00 - 41.00 / 29.00

Note:

Fair value measurement for all recurring inputs was performed using an income approach technique.

Credit Risk: The Corporation is exposed to credit risks that may at times be concentrated with certain counterparties, groups of counterparties or customers. Accounts receivable are generated from a diverse domestic and international customer base. The Corporation’s net receivables at September 30, 2012 are concentrated with the following counterparty and customer industry segments: Integrated Oil Companies — 23%, Refiners — 12%, Services — 9%, Government Entities — 8%, Trading Companies — 7% and Real Estate — 7%. The Corporation reduces its risk related to certain counterparties by using master netting arrangements and requiring collateral, generally cash or letters of credit. The Corporation records the cash collateral received or posted as an offset to the fair value of derivatives executed with the same counterparty. At September 30, 2012 and December 31, 2011, the Corporation held cash from counterparties of $98 million and $121 million, respectively. The Corporation posted cash to counterparties at September 30, 2012 and December 31, 2011 of $22 million and $117 million, respectively.

At September 30, 2012, the Corporation had outstanding letters of credit totaling $1.1 billion, primarily issued to satisfy margin requirements. Certain of the Corporation’s agreements also contain contingent collateral provisions that could require the Corporation to post additional collateral if the Corporation’s credit rating declines. As of September 30, 2012, the net liability related to derivatives with contingent collateral provisions was $467 million before cash collateral posted of $6 million. At September 30, 2012, all three major credit rating agencies that rate the Corporation’s debt had assigned an investment grade rating. If two of the three agencies were to downgrade the Corporation’s rating to below investment grade, as of September 30, 2012, the Corporation would be required to post additional collateral of approximately $270 million.

Subsequent Events

9 Months Ended

Sep. 30, 2012

Subsequent Events

16. Subsequent Events

In October 2012, the Corporation completed the sale of its interests in the Bittern Field (Hess 28%) in the United Kingdom North Sea and the associated Triton floating production, storage and offloading vessel for cash proceeds of approximately $190 million after normal post-closing adjustments.

In October 2012, the Corporation announced an agreement to sell its interests in the Beryl fields (Hess 22%) in the United Kingdom North Sea for $525 million before normal post-closing adjustments. The transaction is expected to close in the first quarter of 2013.

Basis of Presentation (Policies)	9 Months Ended
Basis of Presentation (Policies)	Sep. 30, 2012
Comprehensive Income	Effective January 1, 2012, the Corporation adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income, which requires comprehensive income to be presented either at the end of the income statement or as a separate statement immediately following the income statement. The Corporation elected to adopt the separate statement method.
Fair Value Measurements	Effective January 1, 2012, the Corporation adopted FASB ASU 2011-04, Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRS. For the Corporation, this standard requires additional disclosures related to fair value measurements, which are included in Note 15, Risk Management and Trading Activities.

Inventories (Tables)

9 Months Ended

Sep. 30, 2012

Inventories

Inventories were as follows:


	September 30,			December 31,
	2012			2011
	(In millions)
Crude oil and other charge stocks	$	533		$	451
Refined petroleum products and natural gas		1,367			1,762
Less: LIFO adjustment		(1,209	)		(1,276	)

		691			937
Merchandise, materials and supplies		527			486

Total inventories	$	1,218		$	1,423

Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2012

Net changes in capitalized exploratory well costs


Balance at January 1	$	2,022
Additions to capitalized exploratory well costs pending the determination of proved reserves		406
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(30	)
Capitalized exploratory well costs charged to expense		(124	)

Balance at end of period	$	2,274

- Definition

Tabular disclosure of the aggregate of costs (whether the costs are capitalized or charged to expense at the time they are incurred ) incurred for the year in oil and gas property acquisition, exploration and development activities.

+ References + Details

Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2012

Changes to corporation asset retirement obligations

The following table describes changes to the Corporation’s asset retirement obligations:


	September 30,			December 31,
	2012			2011
	(In millions)
Asset retirement obligations at beginning of period	$	2,071		$	1,358
Liabilities incurred		229			25
Liabilities settled or disposed of		(274	)		(334	)
Accretion expense		101			96
Revisions of estimated liabilities		505			947
Foreign currency translation		42			(21	)

Asset retirement obligations at end of period		2,674			2,071
Less: current obligations		379			227

Long-term obligations at end of period	$	2,295		$	1,844

Foreign Currency (Tables)

9 Months Ended

Sep. 30, 2012

Pre-tax foreign currency gains (losses)

Pre-tax foreign currency gains (losses) amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Pre-tax foreign currency gains (losses)	$	17	$	(9	)	$	25	$	(18	)

Retirement Plans (Tables)

9 Months Ended

Sep. 30, 2012

Components of net periodic pension cost

Components of net periodic pension cost consisted of the following:


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2012			2011			2012			2011
	(In millions)
Service cost	$	19		$	15		$	55		$	43
Interest cost		22			23			66			67
Expected return on plan assets		(29	)		(28	)		(87	)		(82	)
Amortization of net loss		21			13			63			35

Pension expense	$	33		$	23		$	97		$	63

- Definition

Tabular disclosure of one or more of the entity's defined benefit pension plans or one or more other defined benefit postretirement plans, separately for pension plans and other postretirement benefit plans including the entity's schedule of fair value of plan assets for defined benefit or other postretirement plans.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e2439-114920

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e2417-114920

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e2410-114920

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e1928-114920

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 55
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=21916443&loc=d3e4179-114921

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 158
-Paragraph 4, 7, 16, 20, 21
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5, 6, 7
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2012

Provision (benefit) for income taxes

The provision (benefit) for income taxes consisted of the following:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Current	$	509		$	169		$	1,416		$	1,073
Deferred		(114	)		(252	)		(162	)		(253	)
Adjustment to deferred tax liabilities for foreign income tax rate change (*)		115			29			115			29

Total provision (benefit) for income taxes	$	510		$	(54	)	$	1,369		$	849

(*)

Weighted Average Common Shares (Tables)

9 Months Ended

Sep. 30, 2012

Weighted average number of common shares outstanding - basic and diluted

The weighted average number of common shares used in the basic and diluted earnings per share computations is as follows:


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2012		2011		2012		2011
	(In thousands)
Common shares—basic		338,570		337,380		338,325		336,721
Effect of dilutive securities
Restricted common stock		963		1,268		1,029		1,372
Stock options		417		1,574		916		1,745

Common shares—diluted		339,950		340,222		340,270		339,838

Segment Information (Tables)

9 Months Ended

Sep. 30, 2012

Operating revenues by operating segment

The Corporation’s results by operating segment were as follows:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Operating revenues
Exploration and Production	$	3,072		$	2,217		$	9,292		$	7,760
Marketing and Refining		6,140			6,479			18,933			21,071
Less: Transfers between affiliates		(18	)		(31	)		(45	)		(98	)

Total (*)	$	9,194		$	8,665		$	28,180		$	28,733

Net income (loss) attributable to Hess Corporation
Exploration and Production	$	608		$	422		$	1,887		$	2,148
Marketing and Refining		53			(23	)		72			(23	)
Corporate, including interest		(104	)		(101	)		(308	)		(291	)

Total	$	557		$	298		$	1,651		$	1,834

(*)	Operating revenues exclude excise and similar taxes of approximately $640 million and $600 million for the three months ended September 30, 2012 and 2011, respectively, and $1,930 million and $1,750 million for the nine months ended September 30, 2012 and 2011, respectively.

Identifiable assets by operating segment

Identifiable assets by operating segment were as follows:


	September 30, 2012		December 31, 2011
	(In millions)
Exploration and Production	$	36,031	$	32,323
Marketing and Refining		5,211		6,302
Corporate		970		511

Total	$	42,212	$	39,136

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References + Details

Risk Management and Trading Activities (Tables)

9 Months Ended

Sep. 30, 2012

Net Pre-Tax Gains on Derivative Contracts Used for Corporate Risk Management not Designated as Hedges

Net realized and unrealized pre-tax gains (losses) on derivative contracts used for Corporate risk management activities and not designated as hedges amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Commodity	$	—	$	—		$	—	$	1
Foreign exchange		31		(25	)		35		(12	)

Total	$	31	$	(25	)	$	35	$	(11	)

Pre-Tax Gains (Losses) from Trading Activities

Pre-tax unrealized and realized gains (losses) recorded in Sales and other operating revenues in the Statement of Consolidated Income from trading activities amounted to the following:


	Three Months Ended September 30,					Nine Months Ended September 30,
	2012		2011			2012		2011
	(In millions)
Commodity	$	75	$	(5	)	$	83	$	45
Foreign exchange		1		7			3		(1	)
Other		9		(52	)		8		(42	)

Total	$	85	$	(50	)	$	94	$	2

Gross and Net Fair Values of the Corporation's Risk Management and Trading Derivative Instruments

The table below reflects the gross and net fair values of the Corporation’s risk management and trading derivative instruments:


	Accounts Receivable			Accounts Payable
	(In millions)
September 30, 2012
Derivative contracts designated as hedging instruments
Commodity	$	61		$	(144	)
Interest rate and other		72			(2	)

Total derivative contracts designated as hedging instruments		133			(146	)


Derivative contracts not designated as hedging instruments (*)
Commodity		5,505			(5,499	)
Foreign exchange		26			(1	)
Other		16			(7	)

Total derivative contracts not designated as hedging instruments		5,547			(5,507	)


Gross fair value of derivative contracts		5,680			(5,653	)
Master netting arrangements		(4,666	)		4,666
Cash collateral (received) posted		(98	)		22

Net fair value of derivative contracts	$	916		$	(965	)

December 31, 2011
Derivative contracts designated as hedging instruments
Commodity	$	181		$	(216	)
Other		61			(3	)

Total derivative contracts designated as hedging instruments		242			(219	)


Derivative contracts not designated as hedging instruments (*)
Commodity		9,350			(9,823	)
Foreign exchange		6			(21	)
Other		12			(24	)

Total derivative contracts not designated as hedging instruments		9,368			(9,868	)


Gross fair value of derivative contracts		9,610			(10,087	)
Master netting arrangements		(7,962	)		7,962
Cash collateral (received) posted		(121	)		117

Net fair value of derivative contracts	$	1,527		$	(2,008	)

(*)

Includes trading derivatives and derivatives used for risk management.

Fair Values for Corportation's Net Physical Derivative Financial Assets and Liabilities

The following table provides the fair values for the Corporation’s net physical derivative and financial assets and (liabilities) that are based on this hierarchy:


	Level 1			Level 2			Level 3			Collateral and counterparty netting			Balance
	(In millions)
September 30, 2012
Assets
Derivative contracts
Commodity	$	168		$	668		$	240		$	(88	)	$	988
Foreign exchange		—			26			—			—			26
Interest rate and other		6			73			3			—			82
Collateral and counterparty netting		(2	)		(73	)		(7	)		(98	)		(180	)

Total derivative contracts		172			694			236			(186	)		916
Other assets measured at fair value on a recurring basis		1			3			—			—			4

Total assets measured at fair value on a recurring basis	$	173		$	697		$	236		$	(186	)	$	920


Liabilities
Derivative contracts
Commodity	$	(144	)	$	(884	)	$	(125	)	$	88		$	(1,065	)
Foreign exchange		—			(1	)		—			—			(1	)
Other		(1	)		(2	)		—			—			(3	)
Collateral and counterparty netting		2			73			7			22			104

Total derivative contracts		(143	)		(814	)		(118	)		110			(965	)
Other liabilities measured at fair value on a recurring basis		(31	)		(4	)		(1	)		—			(36	)

Total liabilities measured at fair value on a recurring basis	$	(174	)	$	(818	)	$	(119	)	$	110		$	(1,001	)

Other fair value measurement disclosures Long-term debt	$	—		$	(8,737	)	$	—		$	—		$	(8,737	)


December 31, 2011
Assets
Derivative contracts
Commodity	$	135		$	1,188		$	511		$	(67	)	$	1,767
Interest rate and other		—			66			—			—			66
Collateral and counterparty netting		(33	)		(148	)		(4	)		(121	)		(306	)

Total derivative contracts		102			1,106			507			(188	)		1,527
Other assets measured at fair value on a recurring basis		7			34			—			(2	)		39

Total assets measured at fair value on a recurring basis	$	109		$	1,140		$	507		$	(190	)	$	1,566

December 31, 2011
Liabilities
Derivative contracts
Commodity	$	(191	)	$	(1,501	)	$	(650	)	$	67		$	(2,275	)
Foreign exchange		—			(15	)		—			—			(15	)
Other		—			(18	)		(2	)		—			(20	)
Collateral and counterparty netting		33			148			4			117			302

Total derivative contracts		(158	)		(1,386	)		(648	)		184			(2,008	)
Other liabilities measured at fair value on a recurring basis		—			(52	)		(2	)		2			(52	)

Total liabilities measured at fair value on a recurring basis	$	(158	)	$	(1,438	)	$	(650	)	$	186		$	(2,060	)

Other fair value measurement disclosures Long-term debt	$	—		$	(7,317	)	$	—		$	—		$	(7,317	)

Changes in Physical Derivatives and Financial Assets and (Liabilities) that are Measured at Fair Value Based on Level 3 Inputs

The following table provides changes in physical derivatives and financial assets and (liabilities) that are measured at fair value based on Level 3 inputs:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Balance at beginning of period	$	87		$	372		$	(143	)	$	412
Unrealized pre-tax gains (losses)
Included in earnings (a)		(26	)		(85	)		(72	)		19
Included in other comprehensive income (b)		—			13			43			30
Purchases (c)		14			415			244			1,932
Sales (c)		(9	)		(536	)		(266	)		(2,131	)
Settlements (d)		15			(162	)		232			(194	)
Transfers into Level 3		50			(222	)		100			(211	)
Transfers out of Level 3		(14	)		(39	)		(21	)		(101	)

Balance at end of period	$	117		$	(244	)	$	117		$	(244	)

(a)

(b)

The unrealized pre-tax gains (losses) included in Other comprehensive income are reflected in the Change in fair value of cash flow hedges in the Statement of Consolidated Comprehensive Income.

(c)

Purchases and sales primarily represent option premiums paid or received, respectively, during the reporting period.

(d)

Settlements represent realized gains and (losses) on derivatives settled during the reporting period.

Net transfers into and out of each level of the fair value hierarchy

The following table provides net transfers into and out of each level of the fair value hierarchy:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(In millions)
Transfers into Level 1	$	85		$	(4	)	$	244		$	(12	)
Transfers out of Level 1		(38	)		39			210			318

	$	47		$	35		$	454		$	306


Transfers into Level 2	$	48		$	28		$	(245	)	$	34
Transfers out of Level 2		(131	)		198			(288	)		(28	)

	$	(83	)	$	226		$	(533	)	$	6


Transfers into Level 3	$	50		$	(222	)	$	100		$	(211	)
Transfers out of Level 3		(14	)		(39	)		(21	)		(101	)

	$	36		$	(261	)	$	79		$	(312	)

The Corporation's unobservable inputs used in fair value measurements

The following table provides information about the Corporation’s significant recurring unobservable inputs used in the Level 3 fair value measurements.


	Unit of Measurement	Range / Weighted Average
September 30, 2012
Assets
Commodity contracts with a fair value of $240 million Contract prices
Crude oil and refined petroleum products	$ / bbl	$	86.99 - 151.52 / 115.69
Electricity	$ / MWH	$	24.65 - 84.38 / 50.69

Basis prices
Natural gas	$ / MMBTU	$	(0.60) - 4.59 / 0.33

Contract volatilities
Crude oil and refined petroleum products	%		22.00 - 31.00 / 29.00
Natural gas	%		22.00 - 23.00 / 22.00
Electricity	%		18.00 - 31.00 / 26.00

September 30, 2012
Liabilities
Commodity contracts with a fair value of $125 million Contract prices
Crude oil and refined petroleum products	$ / bbl	$	86.98 - 156.53 / 116.25
Electricity	$ / MWH	$	24.65 -84.38 / 51.09

Basis prices
Natural gas	$ / MMBTU	$	(0.55) -4.55 / 0.86

Contract volatilities
Crude oil and refined petroleum products	%		28.00 - 31.00 / 30.00
Natural gas	%		22.00 - 41.00 / 29.00

Note:

Fair value measurement for all recurring inputs was performed using an income approach technique.

Energy Marketing [Member]

Gross volume of the Corporation's derivative instruments outstanding

The table below shows the gross volume of the Corporation’s energy marketing commodity contracts outstanding:


	September 30,		December 31,
	2012		2011
Crude oil and refined petroleum products (millions of barrels)		28		28
Natural gas (millions of mcf)		2,961		2,616
Electricity (millions of megawatt hours)		336		244

Corporate Risk Management [Member]

Gross volume of the Corporation's derivative instruments outstanding

The table below shows the gross volume of the Corporate risk management derivative contracts outstanding:


	September 30,		December 31,
	2012		2011
Commodity, primarily crude oil (millions of barrels)		21		51
Foreign exchange (millions of U.S. Dollars)	$	998	$	900
Interest rate swaps (millions of U.S. Dollars)	$	880	$	895

Trading [Member]

Gross volume of the Corporation's derivative instruments outstanding

The table below shows the gross volume of derivative contracts outstanding relating to trading activities:


	September 30,		December 31,
	2012		2011
Commodity
Crude oil and refined petroleum products (millions of barrels)		1,662		2,169
Natural gas (millions of mcf)		4,109		4,203
Electricity (millions of megawatt hours)		84		304
Foreign exchange (millions of U.S. Dollars)	$	374	$	581
Other
Interest rate (millions of U.S. Dollars)	$	176	$	182
Equity securities (millions of shares)		12		16

Dispositions - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2012 USD ($) boepd	Sep. 30, 2011 USD ($) boepd
Significant Acquisitions and Disposals [Line Items]
Cash proceeds from asset sales	$ 656	$ 490
United Kingdom North Sea and Norway [Member]
Significant Acquisitions and Disposals [Line Items]
Cash proceeds from asset sales		$ 131
Net productive capacity of disposed assets (in boepd) \| boepd		2,500
Gain on asset sale - tax free		$ 103
United Kingdom North Sea [Member]
Significant Acquisitions and Disposals [Line Items]
Cash proceeds from asset sales		359
Gain on asset sale - before tax		343
Gain on asset sale - after tax		$ 310
Net productive capacity of disposed assets (in boepd) \| boepd		15,000
Schiehallion Field [Member]
Significant Acquisitions and Disposals [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	16.00%
Cash proceeds from asset sales	$ 524
Gain on asset sale - before tax	376
Gain on asset sale - after tax	349
Goodwill written off related to sale of business unit	$ 27
Net productive capacity of disposed assets (in boepd) \| boepd	9,000
Snohvit [Member]
Significant Acquisitions and Disposals [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	3.00%
Cash proceeds from asset sales	$ 132
Gain on asset sale - after tax	$ 36
Net productive capacity of disposed assets (in boepd) \| boepd	3,000
Goodwill	$ 14
Snorre Field [Member]
Significant Acquisitions and Disposals [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)		1.00%
Cook Field [Member]
Significant Acquisitions and Disposals [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)		28.00%

Inventories - Inventories (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011
Inventories [Line Items]
Crude oil and other charge stocks	$ 533	$ 451
Refined petroleum products and natural gas	1,367	1,762
Less: LIFO adjustment	(1,209)	(1,276)
Total net crude oil, natural gas and refined petroleum product inventories	691	937
Merchandise, materials and supplies	527	486
Total inventories	$ 1,218	$ 1,423

Property, Plant and Equipment - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended		9 Months Ended
	Oct. 31, 2012	Aug. 31, 2012	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Capitalized Exploratory [Line Items]
Proceeds from asset sales			$ 656	$ 490
Carrying amount of properties classified as held for sale reported in other current assets			1,179
Goodwill			2,208		$ 2,305
Assets retirement obligations and deferred income taxes reported in accrued liabilities			618
Exploratory well costs which were incurred and subsequently expensed			86
Capitalized exploratory well costs greater than one year old after completion of drilling			$ 1,770
Capitalized well costs attributable to Pony Project			37.00%
Capitalized well costs attributable to Block WA-390-P offshore Western Australia			37.00%
Capitalized well costs attributable to Area 54 offshore Libya			15.00%
Capitalized well costs attributable to Ghana			7.00%
Bittern and Schiehallion Fields [Member]
Capitalized Exploratory [Line Items]
Goodwill			$ 112
Bittern Field [Member]
Capitalized Exploratory [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)			28.00%
Bittern Field [Member] \| Subsequent Event [Member]
Capitalized Exploratory [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	28.00%
Proceeds from asset sales	$ 190
Azeri-Chirag-Guneshli (ACG) fields [Member]
Capitalized Exploratory [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)			3.00%
Baku-Tbilisi-Ceyhan (BTC) pipeline [Member]
Capitalized Exploratory [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)			2.00%
Beryl fields [Member] \| Subsequent Event [Member]
Capitalized Exploratory [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	22.00%
Proceeds from asset sales	$ 525
Baku-Tbilisi-Ceyhan Pipeline And Azeri-Chirag-Guneshli Fields [Member]
Capitalized Exploratory [Line Items]
Proceeds from asset sales			$ 1,000
Knotty Head [Member]
Capitalized Exploratory [Line Items]
Working interest per exchange agreement (percentage)		20.00%

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2012 USD ($)
Capitalized Exploratory [Line Items]
Balance at January 1	$ 2,022
Additions to capitalized exploratory well costs pending the determination of proved reserves	406
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(30)
Capitalized exploratory well costs charged to expense	(124)
Balance at end of period	$ 2,274

Asset Impairments - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Impairment [Line Items]
Impairment charge before income tax	$ 208		$ 358	$ 267	$ 358
Corporation's Non-producing Properties [Member]
Impairment [Line Items]
Impairment charge before income tax	208		358
Impairment charge after income tax	$ 116		$ 140
Eagle Ford Properties in Texas [Member]
Impairment [Line Items]
Impairment charge before income tax		$ 59
Impairment charge after income tax		$ 36

Libyan Operations - Additional Information (Detail)	3 Months Ended
Libyan Operations - Additional Information (Detail)	Sep. 30, 2012 boepd
Libyan Operations [Member]
Libyan Operations [Line Items]
The average production in Libya (in boepd)	23,000

Asset Retirement Obligations - Changes to Corporation Asset Retirement Obligations (Detail) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2012	Dec. 31, 2011
Asset Retirement Obligations [Line Items]
Asset retirement obligations at beginning of period	$ 2,071	$ 1,358
Liabilities incurred	229	25
Liabilities settled or disposed of	(274)	(334)
Accretion expense	101	96
Revisions of estimated liabilities	505	947
Foreign currency translation	42	(21)
Asset retirement obligations at end of period	2,674	2,071
Less: current obligations	379	227
Long-term obligations at end of period	$ 2,295	$ 1,844

HOVENSA L.L.C. Joint Venture - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($)
The corporation's future funding commitments for costs related to refinery shutdown recorded in current liabilities on the consolidated balance sheet	$ 487

Debt - Additional Information (Detail) $ in Millions	3 Months Ended	9 Months Ended
Debt - Additional Information (Detail) $ in Millions	Sep. 30, 2012 USD ($)	Sep. 30, 2012 USD ($)
Debt [Line Items]
Net borrowings of debt	$ 1,599	$ 1,599
Borrowings under revolving credit facility		1,000
Borrowings under short-term facilities	583	583
Borrowings under Asset-Backed Facility		68
Net repayment relating to other debt		52
Facilities classified as long-term debt		521
Borrowing capacity under the syndicated revolving credit facility	4,000	4,000
Leased Floating Production System at Tubular Bells Project [Member]
Debt [Line Items]
Additional noncash debt		$ 138
Retail Gasoline Stations [Member]
Debt [Line Items]
Additional noncash debt	$ 47

Foreign Currency - Pre-Tax Foreign Currency Gains (Losses) (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Pre-tax foreign currency gains (losses)	$ 17	$ (9)	$ 25	$ (18)

- Definition

The aggregate foreign currency transaction gain (loss) (both realized and unrealized) included in determining net income for the reporting period. Excludes foreign currency transactions designated as hedges of net investment in a foreign entity and intercompany foreign currency transactions that are of a long-term nature, when the entities to the transaction are consolidated, combined, or accounted for by the equity method in the reporting enterprise's financial statements. For certain enterprises, primarily banks, that are dealers in foreign exchange, foreign currency transaction gains (losses) may be disclosed as dealer gains (losses).

+ References + Details

Retirement Plans - Components of Net Periodic Pension Cost (Detail) - Pension Plans [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 19	$ 15	$ 55	$ 43
Interest cost	22	23	66	67
Expected return on plan assets	(29)	(28)	(87)	(82)
Amortization of net loss	21	13	63	35
Pension expense	$ 33	$ 23	$ 97	$ 63

- Definition

An amount calculated as a basis for determining the extent of delayed recognition of the effects of changes in the fair value of assets. The expected return on plan assets is determined based on the expected long-term rate of return on plan assets and the market-related value of plan assets.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 30
-Glossary Expected Return on Plan Assets
-URI http://asc.fasb.org/extlink&oid=6512136

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 60
-Glossary Expected Return on Plan Assets
-URI http://asc.fasb.org/extlink&oid=6512171

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (h)(3)
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e1928-114920

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph h
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

The increase in a defined benefit pension plan's projected benefit obligation or a defined benefit postretirement plan's accumulated postretirement benefit obligation due to the passage of time.

+ References + Details

- Definition

The actuarial present value of benefits attributed by the pension benefit formula to services rendered by employees during the period. The portion of the expected postretirement benefit obligation attributed to employee service during the period. The service cost component is a portion of the benefit obligation and is unaffected by the funded status of the plan.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Service Cost (Component of Net Periodic Pension Cost)
-URI http://asc.fasb.org/extlink&oid=6525008

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (h)(1)
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e1928-114920

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e1928-114920

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph a, h
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Retirement Plans - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2012 USD ($)
Retirement Plans [Line Items]
Corporation expects to contribute to its pension plans 2012	$ 150
Corporation contributed to its pension plans	$ 116

Income Taxes - Provision (Benefit) for Income Taxes (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2012

Sep. 30, 2011

Income Tax Expense Benefit [Line Items]

Current

$ 509

$ 169

$ 1,416

$ 1,073

Deferred

(114)

(252)

(162)

(253)

Adjustment to deferred tax liabilities for foreign income tax rate change

^[1]

115

Total provision (benefit) for income taxes

$ 510

$ (54)

$ 1,369

$ 849

[1]

- Definition

The component of income tax expense for the period representing amounts of income taxes paid or payable (or refundable) for the period for all income tax obligations as determined by applying the provisions of relevant enacted tax laws to relevant amounts of taxable Income or Loss from continuing operations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Income Taxes - Provision (Benefit) for Income Taxes (Parenthetical) (Detail)	1 Months Ended
	Jul. 31, 2012	Jul. 31, 2011
Petroleum Operations [Member]
Income Tax Expense Benefit [Line Items]
Old supplementary tax rate (in percentage)		20.00%
New supplementary tax rate (in percentage)		32.00%
Dismantlement Expenses [Member]
Income Tax Expense Benefit [Line Items]
Old supplementary tax rate (in percentage)	32.00%
New supplementary tax rate (in percentage)	20.00%

Weighted Average Common Shares - Weighted Average Number of Common Shares Outstanding - Basic and Diluted (Detail) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Weighted Average Shares Used In Computing Earnings Per Share [Line Items]
Common shares-basic	338,570	337,380	338,325	336,721
Effect of dilutive securities
Restricted common stock	963	1,268	1,029	1,372
Stock options	417	1,574	916	1,745
Common shares-diluted	339,950	340,222	340,270	339,838

- Definition

Additional shares included in the calculation of diluted EPS as a result of the potentially dilutive effect of call options and warrants using the treasury stock method.

+ References + Details

- Definition

The average number of shares or units issued and outstanding that are used in calculating diluted EPS or earnings per unit (EPU), determined based on the timing of issuance of shares or units in the period.

+ References + Details

- Definition

Number of [basic] shares or units, after adjustment for contingently issuable shares or units and other shares or units not deemed outstanding, determined by relating the portion of time within a reporting period that common shares or units have been outstanding to the total time in that period.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 45
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=7655603&loc=d3e1448-109256

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Weighted-Average Number of Common Shares Outstanding
-URI http://asc.fasb.org/extlink&oid=6528421

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 07-4
-Paragraph 4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 171
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 40
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Weighted Average Common Shares - Additional Information (Detail)	3 Months Ended		9 Months Ended
	Sep. 30, 2012 shares	Sep. 30, 2011 shares	Sep. 30, 2012 Company shares	Sep. 30, 2011 shares
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Restricted stock awarded to officers			50.00%
PSU shares awarded annually to officers			50.00%
Number of predetermined peer companies \| Company			15
Performance of predetermined peer companies			3 years
Minimum PSU award payout			0.00%
Maximum PSU award payout			200.00%
Restricted stock issued			1,561,300	734,005
Performance shares issued			420,628
Stock options issued				2,201,445
Out-of-the money options	11,519,000	4,180,000	8,810,000	2,763,000
Performance Share Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Out-of-the money options	412,977		412,977

Segment Information - Operating Revenues by Operating Segment (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Operating revenues
Total Operating revenues	$ 9,194	$ 8,665	$ 28,180	$ 28,733
Less: Transfers between affiliates	(18)	(31)	(45)	(98)
Net income (loss) attributable to Hess Corporation
Net income (loss) attributable to Hess Corporation	557	298	1,651	1,834
Exploration and Production [Member]
Operating revenues
Total Operating revenues	3,072	2,217	9,292	7,760
Net income (loss) attributable to Hess Corporation
Net income (loss) attributable to Hess Corporation	608	422	1,887	2,148
Marketing and Refining [Member]
Operating revenues
Total Operating revenues	6,140	6,479	18,933	21,071
Net income (loss) attributable to Hess Corporation
Net income (loss) attributable to Hess Corporation	53	(23)	72	(23)
Corporate and Interest [Member]
Net income (loss) attributable to Hess Corporation
Net income (loss) attributable to Hess Corporation	$ (104)	$ (101)	$ (308)	$ (291)

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Net Income
-URI http://asc.fasb.org/extlink&oid=6518256

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04.19)
-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 225
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.18)
-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04.22)
-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Other Comprehensive Income
-URI http://asc.fasb.org/extlink&oid=6519514

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=20435746&loc=d3e565-108580

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 130
-Paragraph 10, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph A7
-Appendix A

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 87-21
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 03
-Paragraph 19
-Article 5

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 95
-Paragraph 28, 29, 30
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Paragraph 20
-Article 9

+ Details

Segment Information - Operating Revenues by Operating Segment (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Segment Reporting Information [Line Items]
Excise and Similar Taxes	$ 640	$ 600	$ 1,930	$ 1,750

Segment Information - Identifiable Assets By Operating Segment (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011
Schedule Of Identifiable Assets By Segment [Line Items]
Assets	$ 42,212	$ 39,136
Exploration and Production [Member]
Schedule Of Identifiable Assets By Segment [Line Items]
Assets	36,031	32,323
Marketing and Refining [Member]
Schedule Of Identifiable Assets By Segment [Line Items]
Assets	5,211	6,302
Corporate [Member]
Schedule Of Identifiable Assets By Segment [Line Items]
Assets	$ 970	$ 511

Risk Management and Trading Activities - Additional Information (Detail) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012 USD ($) bbl $ / bbl	Sep. 30, 2011 USD ($)	Sep. 30, 2012 USD ($) bbl $ / bbl	Sep. 30, 2011 USD ($)	Dec. 31, 2011 USD ($)
Derivative [Line Items]
Voting interest in trading partnership			50.00%
The length of time over which the Corporation hedges exposure to variability in future cash flows (in number of years)			One year or less
Maximum duration for the outstanding hedging contracts (in number of years)			2 years
Hedge contracts associated with the termination of Brent crude oil cash flow hedges covering the period through 2012 (barrels per day) \| bbl			24,000
Total number of barrels per day hedged based on new Brent crude oil cash flow hedges \| bbl	120,000		120,000
Average price for hedges (per barrel) \| $ / bbl	107.70		107.70
Gross notional amount of interest rate swaps	$ 880		$ 880
Percentage of Information disclosed for trading partnership			100.00%
Cash received as collateral	98		$ 98		$ 121
Corporation posted cash to counterparties	22		22		117
Outstanding letters of credit	1,100		1,100
Net liability related to derivatives with contingent collateral provisions	467		467
Cash collateral posted for derivatives with contingent collateral provisions	6		6
Additional collateral	270		270
New Brent Crude Hedges [Member]
Derivative [Line Items]
Change in the carrying value of the hedged fixed rate debt - increase/(decrease)	7	$ 42	17	$ 45
Change in the fair value of interest rate swaps - increase/(decrease)	7	42	17	45
Energy Marketing Activities [Member]
Derivative [Line Items]
After tax deferred losses in Accumulated other comprehensive income	35		35		64
Reclassification of accumulated other comprehensive income/(losses) into earnings over the next twelve months			(22)
Corporation reclassified after-tax gains/(losses) from accumulated other comprehensive income to earnings	6	(24)	(45)	(77)
Gain (loss) from hedge ineffectiveness reflected in earnings	(1)	(2)	(1)	(4)
Increase (decrease) in after-tax deferred losses related to fair value of energy marketing cash flow hedge positions	(11)	4	16	1
Energy Marketing Activities [Member] \| Not designated as hedges [Member]
Derivative [Line Items]
Net realized and unrealized pre-tax gains on derivative contracts not designated as hedges	$ 66	8	$ 145	36
Trading Activities [Member]
Derivative [Line Items]
Voting interest in trading partnership			50.00%
Integrated Oil Companies [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	23.00%		23.00%
Refiners [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	12.00%		12.00%
Government Entities [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	8.00%		8.00%
Services [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	9.00%		9.00%
Trading Companies [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	7.00%		7.00%
Real estate funds [Member]
Derivative [Line Items]
Fair value, concentration of risk, accounts receivable	7.00%		7.00%
Corporate Risk Management [Member] \| New Brent Crude Hedges [Member]
Derivative [Line Items]
Gain (loss) from hedge ineffectiveness reflected in earnings	$ (2)		$ (10)
Corporate Risk Management [Member] \| Not designated as hedges [Member]
Derivative [Line Items]
Net realized and unrealized pre-tax gains on derivative contracts not designated as hedges	31	(25)	35	(11)
Corporate Risk Management [Member] \| Closed Brent Crude Hedges [Member]
Derivative [Line Items]
Realized losses from Exploration and Production hedging activities due to the decrease in sales and other operating revenue	148	131	533	387
Realized losses from Exploration and Production hedging activities net of taxes	94	$ 82	334	$ 244
Corporate Risk Management [Member] \| Closed & New Brent Crude Hedges [Member]
Derivative [Line Items]
After tax deferred losses in Accumulated other comprehensive income	$ 115		$ 115		$ 286

Risk Management and Trading Activities - Gross Volume of Corporation's Derivative Instruments Outstanding (Detail) shares in Millions, $ in Millions	Sep. 30, 2012 USD ($) bbl MWh Mcf shares	Dec. 31, 2011 USD ($) bbl MWh Mcf shares
Derivative [Line Items]
Interest rate swaps (millions of U.S. Dollars)	$ 880
Gross Volume of the corporate risk management derivative instruments outstanding [Member]
Derivative [Line Items]
Foreign exchange (millions of U.S. Dollars)	998	$ 900
Interest rate swaps (millions of U.S. Dollars)	880	895
Gross Volume of Derivative Instruments Outstanding Relating to Trading Activities [Member]
Derivative [Line Items]
Foreign exchange (millions of U.S. Dollars)	374	581
Interest rate swaps (millions of U.S. Dollars)	$ 176	$ 182
Commodity, primarily crude oil (millions of barrels) [Member] \| Gross Volume of the corporate risk management derivative instruments outstanding [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| bbl	21	51
Crude oil and refined petroleum products (millions of barrels) [Member] \| Gross Volume of the Corporation's Energy Marketing Commodity Contracts Outstanding [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| bbl	28	28
Crude oil and refined petroleum products (millions of barrels) [Member] \| Gross Volume of Derivative Instruments Outstanding Relating to Trading Activities [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| bbl	1,662	2,169
Natural gas (millions of mcf) [Member] \| Gross Volume of the Corporation's Energy Marketing Commodity Contracts Outstanding [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| Mcf	2,961	2,616
Natural gas (millions of mcf) [Member] \| Gross Volume of Derivative Instruments Outstanding Relating to Trading Activities [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| Mcf	4,109	4,203
Electricity (millions of megawatt hours) [Member] \| Gross Volume of the Corporation's Energy Marketing Commodity Contracts Outstanding [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| MWh	336	244
Electricity (millions of megawatt hours) [Member] \| Gross Volume of Derivative Instruments Outstanding Relating to Trading Activities [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts \| MWh	84	304
Equity securities (millions of shares) [Member] \| Gross Volume of Derivative Instruments Outstanding Relating to Trading Activities [Member]
Derivative [Line Items]
Equity Securities (millions of shares) \| shares	12	16

Risk Management and Trading Activities - Net Pre-Tax Gains on Derivative Contracts Used for Corporate Risk Management Not Designated As Hedges (Detail) - Corporate Risk Management [Member] - Not designated as hedges [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Net pre-tax gains (losses) on derivative contracts not designated as hedges
Net pre-tax gains (losses) on derivative contracts	$ 31	$ (25)	$ 35	$ (11)
Commodity [Member]
Net pre-tax gains (losses) on derivative contracts not designated as hedges
Net pre-tax gains (losses) on derivative contracts				1
Foreign exchange [Member]
Net pre-tax gains (losses) on derivative contracts not designated as hedges
Net pre-tax gains (losses) on derivative contracts	$ 31	$ (25)	$ 35	$ (12)

Risk Management and Trading Activities - Pre-Tax Gains (Losses) from Trading Activities (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses) from trading activities	$ 85	$ (50)	$ 94	$ 2
Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses) from trading activities	75	(5)	83	45
Foreign exchange [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses) from trading activities	1	7	3	(1)
Other [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses) from trading activities	$ 9	$ (52)	$ 8	$ (42)

Risk Management and Trading Activities - Gross and Net Fair Values of Corporation's Risk Management and Trading Derivative Instruments (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011
Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	$ 133	$ 242
Derivative contracts not designated as hedging instruments	5,547	9,368
Gross fair value of derivative contracts	5,680	9,610
Master netting arrangements	(4,666)	(7,962)
Cash collateral (received) posted	(98)	(121)
Net fair value of derivative contracts	916	1,527
Accounts Receivable [Member] \| Commodity [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	61	181
Derivative contracts not designated as hedging instruments	5,505	9,350
Accounts Receivable [Member] \| Interest rate and other [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	72	61
Accounts Receivable [Member] \| Foreign exchange [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	26	6
Accounts Receivable [Member] \| Other [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	16	12
Accounts Payable [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	(146)	(219)
Derivative contracts not designated as hedging instruments	(5,507)	(9,868)
Gross fair value of derivative contracts	(5,653)	(10,087)
Master netting arrangements	4,666	7,962
Cash collateral (received) posted	22	117
Net fair value of derivative contracts	(965)	(2,008)
Accounts Payable [Member] \| Commodity [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	(144)	(216)
Derivative contracts not designated as hedging instruments	(5,499)	(9,823)
Accounts Payable [Member] \| Interest rate and other [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts designated as hedging instruments	(2)	(3)
Accounts Payable [Member] \| Foreign exchange [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	(1)	(21)
Accounts Payable [Member] \| Other [Member]
Derivatives, Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	$ (7)	$ (24)

Risk Management and Trading Activities - Changes in Financial Assets and Liabilities at Fair Value Based on Level 3 Inputs (Detail) - USD ($) $ in Millions	Sep. 30, 2012	Dec. 31, 2011
Assets
Collateral and counterparty netting	$ (180)	$ (306)
Total derivative contracts (Assets)	916	1,527
Other assets measured at fair value on a recurring basis	4	39
Total assets measured at fair value on a recurring basis	920	1,566
Liabilities
Collateral and counterparty netting	104	302
Total derivative contracts (Liabilities)	(965)	(2,008)
Other liabilities measured at fair value on a recurring basis	(36)	(52)
Total liabilities measured at fair value on a recurring basis	(1,001)	(2,060)
Other fair value measurement disclosures Long-term debt	(8,737)	(7,317)
Commodity [Member]
Assets
Total derivative contracts (Assets)	988	1,767
Liabilities
Total derivative contracts (Liabilities)	(1,065)	(2,275)
Foreign exchange [Member]
Assets
Total derivative contracts (Assets)	26
Liabilities
Total derivative contracts (Liabilities)	(1)	(15)
Interest rate and other [Member]
Assets
Total derivative contracts (Assets)	82	66
Other [Member]
Liabilities
Total derivative contracts (Liabilities)	(3)	(20)
Level 1 [Member]
Assets
Collateral and counterparty netting	(2)	(33)
Total derivative contracts (Assets)	172	102
Other assets measured at fair value on a recurring basis	1	7
Total assets measured at fair value on a recurring basis	173	109
Liabilities
Collateral and counterparty netting	2	33
Total derivative contracts (Liabilities)	(143)	(158)
Other liabilities measured at fair value on a recurring basis	(31)
Total liabilities measured at fair value on a recurring basis	(174)	(158)
Other fair value measurement disclosures Long-term debt
Level 1 [Member] \| Commodity [Member]
Assets
Total derivative contracts (Assets)	168	135
Liabilities
Total derivative contracts (Liabilities)	(144)	(191)
Level 1 [Member] \| Foreign exchange [Member]
Assets
Total derivative contracts (Assets)
Liabilities
Total derivative contracts (Liabilities)
Level 1 [Member] \| Interest rate and other [Member]
Assets
Total derivative contracts (Assets)	6
Level 1 [Member] \| Other [Member]
Liabilities
Total derivative contracts (Liabilities)	(1)
Level 2 [Member]
Assets
Collateral and counterparty netting	(73)	(148)
Total derivative contracts (Assets)	694	1,106
Other assets measured at fair value on a recurring basis	3	34
Total assets measured at fair value on a recurring basis	697	1,140
Liabilities
Collateral and counterparty netting	73	148
Total derivative contracts (Liabilities)	(814)	(1,386)
Other liabilities measured at fair value on a recurring basis	(4)	(52)
Total liabilities measured at fair value on a recurring basis	(818)	(1,438)
Other fair value measurement disclosures Long-term debt	(8,737)	(7,317)
Level 2 [Member] \| Commodity [Member]
Assets
Total derivative contracts (Assets)	668	1,188
Liabilities
Total derivative contracts (Liabilities)	(884)	(1,501)
Level 2 [Member] \| Foreign exchange [Member]
Assets
Total derivative contracts (Assets)	26
Liabilities
Total derivative contracts (Liabilities)	(1)	(15)
Level 2 [Member] \| Interest rate and other [Member]
Assets
Total derivative contracts (Assets)	73	66
Level 2 [Member] \| Other [Member]
Liabilities
Total derivative contracts (Liabilities)	(2)	(18)
Level 3 [Member]
Assets
Collateral and counterparty netting	(7)	(4)
Total derivative contracts (Assets)	236	507
Total assets measured at fair value on a recurring basis	236	507
Liabilities
Collateral and counterparty netting	7	4
Total derivative contracts (Liabilities)	(118)	(648)
Other liabilities measured at fair value on a recurring basis	(1)	(2)
Total liabilities measured at fair value on a recurring basis	(119)	(650)
Other fair value measurement disclosures Long-term debt
Level 3 [Member] \| Commodity [Member]
Assets
Total derivative contracts (Assets)	240	511
Liabilities
Total derivative contracts (Liabilities)	(125)	(650)
Level 3 [Member] \| Foreign exchange [Member]
Assets
Total derivative contracts (Assets)
Liabilities
Total derivative contracts (Liabilities)
Level 3 [Member] \| Interest rate and other [Member]
Assets
Total derivative contracts (Assets)	3
Level 3 [Member] \| Other [Member]
Liabilities
Total derivative contracts (Liabilities)		(2)
Collateral and counterparty netting [Member]
Assets
Collateral and counterparty netting	(98)	(121)
Total derivative contracts (Assets)	(186)	(188)
Other assets measured at fair value on a recurring basis		(2)
Total assets measured at fair value on a recurring basis	(186)	(190)
Liabilities
Collateral and counterparty netting	22	117
Total derivative contracts (Liabilities)	110	184
Other liabilities measured at fair value on a recurring basis		2
Total liabilities measured at fair value on a recurring basis	110	186
Other fair value measurement disclosures Long-term debt
Collateral and counterparty netting [Member] \| Commodity [Member]
Assets
Total derivative contracts (Assets)	(88)	(67)
Liabilities
Total derivative contracts (Liabilities)	88	$ 67
Collateral and counterparty netting [Member] \| Foreign exchange [Member]
Assets
Total derivative contracts (Assets)
Liabilities
Total derivative contracts (Liabilities)
Collateral and counterparty netting [Member] \| Interest rate and other [Member]
Assets
Total derivative contracts (Assets)
Collateral and counterparty netting [Member] \| Other [Member]
Liabilities
Total derivative contracts (Liabilities)

Risk Management and Trading Activities - Fair Value of Corporation's Financial Assets and Liabilities Based on Hierarchy (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2012

Sep. 30, 2011

Fair Value Assets Measured On Recurring Basis [Line Items]

Balance at beginning of period

$ 87

$ 372

$ (143)

$ 412

Unrealized pre-tax gains (losses)

Included in earnings

^[1]

(26)

(85)

(72)

Included in other comprehensive income

^[2]

Purchases

^[3]

415

244

1,932

Sales

^[3]

(9)

(536)

(266)

(2,131)

Settlements

^[4]

(162)

232

(194)

Transfers into Level 3

(222)

100

(211)

Transfers out of Level 3

(14)

(39)

(21)

(101)

Balance at end of period

$ 117

$ (244)

$ 117

$ (244)

[1]	The unrealized pre-tax gains (losses) included in earnings that are reflected in Sales and other operating revenues in the Statement of Consolidated Income amounted to $8 million and $(40) million for the three and nine months ended September 30, 2012, respectively. The unrealized pre-tax gains (losses) included in earnings that are reflected in Cost of products sold in the Statement of Consolidated Income amounted to $(34) million and $(32) million for the three and nine months ended September 30, 2012, respectively.
[2]	The unrealized pre-tax gains (losses) included in Other comprehensive income are reflected in the Change in fair value of cash flow hedges in the Statement of Consolidated Comprehensive Income.
[3]	Purchases and sales primarily represent option premiums paid or received, respectively, during the reporting period.
[4]	Settlements represent realized gains and (losses) on derivatives settled during the reporting period.

Risk Management and Trading Activities - Fair Value of Corporation's Financial Assets and Liabilities Based on Hierarchy (Parenthetical) (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2012

Sep. 30, 2011

Fair Value Assets Measured On Recurring Basis [Line Items]

Unrealized pre-tax gains (losses) reflected in Cost of products sold

^[1]

$ (26)

$ (85)

$ (72)

$ 19

Sales [Member]

Fair Value Assets Measured On Recurring Basis [Line Items]

Level 3 Unrealized pre-tax gains (losses)

(40)

Cost of Sales [Member]

Fair Value Assets Measured On Recurring Basis [Line Items]

Unrealized pre-tax gains (losses) reflected in Cost of products sold

$ (34)

$ (32)

[1]

Risk Management and Trading Activities - Net Transfers Into and out of Each Level of Fair Value Hierarchy (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements net transfers in	$ 85	$ (4)	$ 244	$ (12)
Fair Value Measurements net transfers out	(38)	39	210	318
Fair Value Measurements net transfers into/out of	47	35	454	306
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements net transfers in	48	28	(245)	34
Fair Value Measurements net transfers out	(131)	198	(288)	(28)
Fair Value Measurements net transfers into/out of	(83)	226	(533)	6
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements net transfers in	50	(222)	100	(211)
Fair Value Measurements net transfers out	(14)	(39)	(21)	(101)
Fair Value Measurements net transfers into/out of	$ 36	$ (261)	$ 79	$ (312)

Risk Management and Trading Activities - Corporation's Unobservable Inputs Used in Fair Value Measurements (Parenthetical) (Detail) - Commodity [Member] $ in Millions	Sep. 30, 2012 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Total derivative contracts (Assets)	$ 240
Level 3 [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total derivatives contract (liabilities)	$ 125

Subsequent Events - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	9 Months Ended
	Oct. 31, 2012	Sep. 30, 2012	Sep. 30, 2011
Subsequent Event [Line Items]
Proceeds from asset sales		$ 656	$ 490
Bittern Field [Member]
Subsequent Event [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)		28.00%
Subsequent Event [Member] \| Bittern Field [Member]
Subsequent Event [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	28.00%
Proceeds from asset sales	$ 190
Subsequent Event [Member] \| Beryl fields [Member]
Subsequent Event [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	22.00%
Proceeds from asset sales	$ 525

Risk Management and Trading Activities - Corporation's Unobservable Inputs Used in Fair Value Measurements (Detail)	Sep. 30, 2012 $ / bbl $ / MMBTU $ / MWh
Minimum [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / bbl	86.99
Minimum [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MWh	24.65
Minimum [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MMBTU	(0.60)
Minimum [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	22.00%
Minimum [Member] \| Contract volatilities [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	18.00%
Minimum [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	22.00%
Maximum [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / bbl	151.52
Maximum [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MWh	84.38
Maximum [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MMBTU	4.59
Maximum [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	31.00%
Maximum [Member] \| Contract volatilities [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	31.00%
Maximum [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	23.00%
Weighted Average [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / bbl	115.69
Weighted Average [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MWh	50.69
Weighted Average [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of assets for recurring inputs \| $ / MMBTU	0.33
Weighted Average [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	29.00%
Weighted Average [Member] \| Contract volatilities [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	26.00%
Weighted Average [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of assets for recurring inputs	22.00%
Level 3 [Member] \| Minimum [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / bbl	86.98
Level 3 [Member] \| Minimum [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MWh	24.65
Level 3 [Member] \| Minimum [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MMBTU	(0.55)
Level 3 [Member] \| Minimum [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	28.00%
Level 3 [Member] \| Minimum [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	22.00%
Level 3 [Member] \| Maximum [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / bbl	156.53
Level 3 [Member] \| Maximum [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MWh	84.38
Level 3 [Member] \| Maximum [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MMBTU	4.55
Level 3 [Member] \| Maximum [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	31.00%
Level 3 [Member] \| Maximum [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	41.00%
Level 3 [Member] \| Weighted Average [Member] \| Contract prices [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / bbl	116.25
Level 3 [Member] \| Weighted Average [Member] \| Contract prices [Member] \| Electricity [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MWh	51.09
Level 3 [Member] \| Weighted Average [Member] \| Contract prices [Member] \| Natural gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Range of measurement of liabilities for recurring inputs \| $ / MMBTU	0.86
Level 3 [Member] \| Weighted Average [Member] \| Contract volatilities [Member] \| Crude oil and refined petroleum products [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	30.00%
Level 3 [Member] \| Weighted Average [Member] \| Contract volatilities [Member] \| Natural gas [Member] \| Commodity [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Percentage range of measurement of liabilities for recurring inputs	29.00%