Hess (HES) 10-K 27 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	HES
Entity Registrant Name	HESS CORP
Entity Central Index Key	4447
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	285,834,964
Entity Public Float		$26,590

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$2,444	$1,814
Accounts receivable
Trade	1,642	3,093
Other	431	432
Inventories	527	954
Other current assets	1,643	2,306
Total current assets	6,687	8,599
PROPERTY, PLANT AND EQUIPMENT
Total — at cost	46,522	45,950
Less: Reserves for depreciation, depletion, amortization and lease impairment	19,005	17,179
Property, plant and equipment — net	27,517	28,771
GOODWILL	1,858	1,869
DEFERRED INCOME TAXES	2,169	2,319
OTHER ASSETS	347	1,196
TOTAL ASSETS	38,578	42,754
CURRENT LIABILITIES
Accounts payable	708	2,109
Accrued liabilities	3,781	3,551
Taxes payable	294	520
Short-term debt and current maturities of long-term debt	68	378
Total current liabilities	4,851	6,558
LONG-TERM DEBT	5,919	5,420
DEFERRED INCOME TAXES	2,009	2,292
ASSET RETIREMENT OBLIGATIONS	2,281	2,249
OTHER LIABILITIES AND DEFERRED CREDITS	1,198	1,451
Total liabilities	16,258	17,970
Hess Corporation stockholders’ equity
Common stock, par value $1.00 Authorized — 600,000,000 shares Issued: 2014 — 285,834,964 shares; 2013 — 325,314,177 shares	286	325
Capital in excess of par value	3,277	3,498
Retained earnings	20,052	21,235
Accumulated other comprehensive income (loss)	-1,410	-338
Total Hess Corporation stockholders’ equity	22,205	24,720
Noncontrolling interests	115	64
Total equity	22,320	24,784
TOTAL LIABILITIES AND EQUITY	$38,578	$42,754

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Statement Of Financial Position [Abstract]
Common stock, par value	$1	$1
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	285,834,964	325,314,177

Statement_of_Consolidated_Inco

Statement of Consolidated Income (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES AND NON-OPERATING INCOME
Sales (excluding excise taxes) and other operating revenues	$10,737	$11,905	$12,245
Gains on asset sales, net	823	2,174	584
Other, net	-121	-51	106
Total revenues and non-operating income	11,439	14,028	12,935
COSTS AND EXPENSES
Cost of products sold (excluding items shown separately below)	1,826	1,853	1,333
Operating costs and expenses	1,927	2,116	2,202
Production and severance taxes	275	372	550
Exploration expenses, including dry holes and lease impairment	840	1,031	1,070
General and administrative expenses	588	673	576
Interest expense	323	406	419
Depreciation, depletion and amortization	3,224	2,687	2,866
Asset impairments		289	582
Total costs and expenses	9,003	9,427	9,598
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	2,436	4,601	3,337
Provision for income taxes	744	565	1,529
INCOME FROM CONTINUING OPERATIONS	1,692	4,036	1,808
INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	682	1,186	255
NET INCOME	2,374	5,222	2,063
Less: Net income attributable to noncontrolling interests	57	170	38
NET INCOME ATTRIBUTABLE TO HESS CORPORATION	$2,317	$5,052	$2,025
NET INCOME ATTRIBUTABLE TO HESS CORPORATION PER SHARE
Continuing operations	$5.57	$11.47	$5.29
Discontinued operations	$2.06	$3.54	$0.69
NET INCOME PER SHARE	$7.63	$15.01	$5.98
DILUTED:
Continuing operations	$5.50	$11.33	$5.26
Discontinued operations	$2.03	$3.49	$0.69
NET INCOME PER SHARE	$7.53	$14.82	$5.95
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING (DILUTED)	307.7	340.9	340.3

Statement_of_Consolidated_Comp

Statement of Consolidated Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement Of Income And Comprehensive Income [Abstract]
NET INCOME	$2,374	$5,222	$2,063
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	-137	-33	676
Income taxes on effect of hedge (gains) losses reclassified to income	51	18	-252
Net effect of hedge (gains) losses reclassified to income	-86	-15	424
Change in fair value of cash flow hedges	128	68	-156
Income taxes on change in fair value of cash flow hedges	-48	-25	60
Net change in fair value of cash flow hedges	80	43	-96
Change in derivatives designated as cash flow hedges, after-tax	-6	28	328
Pension and other postretirement plans
Reduction (increase) of unrecognized actuarial losses	-534	414	-100
Income taxes on actuarial changes in plan liabilities	186	-157	39
Reduction (increase) in unrecognized actuarial losses, net	-348	257	-61
Amortization of net actuarial losses	56	63	85
Income taxes on amortization of net actuarial losses	-18	-23	-32
Net effect of amortization of net actuarial losses	38	40	53
Change in pension and other postretirement plans, after-tax	-310	297	-8
Foreign currency translation adjustment
Foreign currency translation adjustment	-756	-283	256
Reclassified to Gains on asset sales, net		119
Change in foreign currency translation adjustment	-756	-164	256
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	-1,072	161	576
COMPREHENSIVE INCOME	1,302	5,383	2,639
Less: Comprehensive income (loss) attributable to noncontrolling interests	57	176	40
COMPREHENSIVE INCOME ATTRIBUTABLE TO HESS CORPORATION	$1,245	$5,207	$2,599

Statement_of_Consolidated_Cash

Statement of Consolidated Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
NET INCOME	$2,374	$5,222	$2,063
Adjustments to reconcile net income to net cash provided by operating activities
(Gains) losses on asset sales	-823	-2,174	-584
Depreciation, depletion and amortization	3,224	2,687	2,866
Loss from equity affiliates	84
Asset impairments		289	582
Exploratory dry hole costs	301	344	377
Exploration lease impairment	207	245	223
Stock compensation expense	87	60	83
Provision (benefit) for deferred income taxes	270	-427	-584
Income from discontinued operations	-682	-1,186	-255
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	-199	-239	125
(Increase) decrease in inventories	62	134	-124
Increase (decrease) in accounts payable and accrued liabilities	86	-603	884
Increase (decrease) in taxes payable	-108	-435	28
Changes in other assets and liabilities	-372	-209	-163
Cash provided by operating activities - continuing operations	4,511	3,708	5,521
Cash provided by (used in) operating activities - discontinued operations	-47	1,162	139
Net cash provided by operating activities	4,464	4,870	5,660
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	-5,274	-5,767	-7,682
Proceeds from asset sales	2,978	4,458	843
Other, net	-139	-227	-64
Cash provided by (used in) investing activities - continuing operations	-2,435	-1,536	-6,903
Cash provided by (used in) investing activities - discontinued operations	2,436	2,114	-148
Net cash provided by (used in) investing activities	1	578	-7,051
CASH FLOWS FROM FINANCING ACTIVITIES
Net borrowings (repayments) of debt with maturities of 90 days or less		-1,748	1,648
Debt with maturities of greater than 90 days
Borrowings	598	535	630
Repayments	-590	-1,271	-433
Common stock acquired and retired	-3,715	-1,493
Cash dividends paid	-303	-235	-171
Noncontrolling interests, net		-182
Employee stock options exercised, including income tax benefits	182	128	11
Cash provided by (used in) financing activities - continuing operations	-3,828	-4,266	1,685
Cash provided by (used in) financing activities - discontinued operations	-7	-10	-3
Net cash provided by (used in) financing activities	-3,835	-4,276	1,682
NET INCREASE IN CASH AND CASH EQUIVALENTS	630	1,172	291
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,814	642	351
CASH AND CASH EQUIVALENTS AT END OF YEAR	$2,444	$1,814	$642

Statement_of_Consolidated_Equi

Statement of Consolidated Equity (USD $)	Total	Common Stock [Member]	Capital in Excess of Par [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Total Hess Stockholders' Equity [Member]	Noncontrolling Interests [Member]
In Millions
Beginning balance at Dec. 31, 2011	$18,592	$340	$3,417	$15,826	($1,067)	$18,516	$76
NET INCOME	2,063			2,025		2,025	38
Other comprehensive income (loss)	576				574	574	2
Comprehensive income (loss)	2,639					2,599	40
Activity related to restricted common stock awards, net	57	2	55			57
Employee stock options, including income tax benefits	44		44			44
Performance share units	8		8			8
Cash dividends declared	-136			-136		-136
Noncontrolling interests, net	-1			2		2	-3
Ending balance at Dec. 31, 2012	21,203	342	3,524	17,717	-493	21,090	113
NET INCOME	5,222			5,052		5,052	170
Other comprehensive income (loss)	161				155	155	6
Comprehensive income (loss)	5,383					5,207	176
Activity related to restricted common stock awards, net	33	1	32			33
Employee stock options, including income tax benefits	139	2	137			139
Performance share units	10		10			10
Common stock acquired and retired	-1,538	-20	-205	-1,313		-1,538
Cash dividends declared	-235			-235		-235
Noncontrolling interests, net	-211			14		14	-225
Ending balance at Dec. 31, 2013	24,784	325	3,498	21,235	-338	24,720	64
NET INCOME	2,374			2,317		2,317	57
Other comprehensive income (loss)	-1,072				-1,072	-1,072
Comprehensive income (loss)	1,302					1,245	57
Activity related to restricted common stock awards, net	61	1	60			61
Employee stock options, including income tax benefits	185	3	182			185
Performance share units	19		19			19
Common stock acquired and retired	-3,722	-43	-482	-3,197		-3,722
Cash dividends declared	-303			-303		-303
Noncontrolling interests, net	-6						-6
Ending balance at Dec. 31, 2014	$22,320	$286	$3,277	$20,052	($1,410)	$22,205	$115

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	1. Summary of Significant Accounting Policies
	Nature of Business:  Hess Corporation (the Registrant) with its subsidiaries (collectively referred to as the Corporation or Hess) is a global Exploration and Production (E&P) company that develops, produces, purchases, transports and sells crude oil, natural gas liquids and natural gas with production operations primarily in the United States (U.S.), Denmark, Equatorial Guinea, the Joint Development Area of Malaysia/Thailand (JDA), Malaysia, and Norway.
	In the first quarter of 2013, the Corporation announced several initiatives to continue its transformation into a focused pure play E&P company. As part of its transformation, the Corporation sold mature or lower margin E&P assets in Azerbaijan, Indonesia, Norway, Russia, Thailand, the United Kingdom (UK) North Sea, and certain interests onshore in the U.S. over the period of 2012 through 2014.  In addition, the transformation plan included fully exiting the Corporation’s Marketing and Refining (M&R) businesses including its terminal, retail, energy marketing, and energy trading operations, as well as the permanent shutdown of refining operations at its Port Reading facility.  HOVENSA L.L.C. (HOVENSA), a 50/50 joint venture between the Corporation’s subsidiary, Hess Oil Virgin Islands Corp. (HOVIC), and a subsidiary of Petroleos de Venezuela S.A. (PDVSA), had previously shut down its United States (U.S.) Virgin Islands refinery in January 2012 and continued operating solely as an oil storage terminal.  All downstream businesses were sold or shutdown as of December 31, 2014, except for the energy trading joint venture, Hess Energy Trading Corporation (HETCO), which was sold in February 2015, and Hovensa.  See Note 2, Discontinued Operations, Note 3, Dispositions, and Note 22, Subsequent Events for additional disclosures related to the divestitures and Note 18, Guarantees and Contingencies for additional information related to HOVENSA in the Notes to the Consolidated Financial Statements.
	Principles of Consolidation and Basis of Presentation:  The consolidated financial statements include the accounts of Hess Corporation and entities in which the Corporation owns more than a 50% voting interest or entities that the Corporation controls. The Corporation consolidates the energy trading joint venture in which it owns a 50% voting interest and over which it exercises control. The Corporation’s undivided interests in unincorporated oil and gas exploration and production ventures are proportionately consolidated. Investments in affiliated companies, 20% to 50% owned and where the Corporation has the ability to influence the operating or financial decisions of the affiliate, are accounted for using the equity method.
	The prior years’ financial information has been recast to reflect consolidated results of operations, cash flows and other information of the Corporation’s divested consolidated downstream businesses, the Port Reading refining facility, and HETCO as discontinued operations. See also Note 2, Discontinued Operations in the Notes to the Consolidated Financial Statements.  Certain other information in the financial statements and notes has been reclassified to conform to the current period presentation.
	Estimates and Assumptions:  In preparing financial statements in conformity with U.S. generally accepted accounting principles (GAAP), management makes estimates and assumptions that affect the reported amounts of assets and liabilities in the Consolidated Balance Sheet and revenues and expenses in the Statement of Consolidated Income. Actual results could differ from those estimates. Estimates made by management include oil and gas reserves, asset and other valuations, depreciable lives, pension liabilities, legal and environmental obligations, asset retirement obligations and income taxes.
	Revenue Recognition:  The Corporation recognizes revenues from the sale of crude oil, natural gas liquids, and natural gas, when title passes to the customer. The Corporation recognizes revenues from the production of natural gas properties based on sales to customers. Differences between E&P natural gas volumes sold and the Corporation’s entitlement share of natural gas production are not material. Sales of refined petroleum products and other merchandise from divested downstream operations were also recognized when title passed to customers.
	In its E&P activities, the Corporation engages in crude oil purchase and sale transactions with the same counterparty that are entered into in contemplation of one another for the primary purpose of changing location or quality. These arrangements are reported net in Sales and other operating revenues in the Statement of Consolidated Income.
	Exploration and Development Costs:  E&P activities are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Annual lease rentals, exploration expenses and exploratory dry hole costs are expensed as incurred. Costs of drilling and equipping productive wells, including development dry holes, and related production facilities are capitalized. In production operations, costs of injected CO2 for tertiary recovery are expensed as incurred.
	The costs of exploratory wells that find oil and gas reserves are capitalized pending determination of whether proved reserves have been found. Exploratory drilling costs remain capitalized after drilling is completed if (1) the well has found a sufficient quantity of reserves to justify completion as a producing well and (2) sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If either of those criteria is not met, or if there is substantial doubt about the economic or operational viability of a project, the capitalized well costs are charged to expense. Indicators of sufficient progress in assessing reserves and the economic and operating viability of a project include commitment of project personnel, active negotiations for sales contracts with customers, negotiations with governments, operators and contractors, firm plans for additional drilling and other factors.
	Depreciation, Depletion and Amortization:  The Corporation records depletion expense for acquisition costs of proved properties using the units of production method over proved oil and gas reserves. Depreciation and depletion expense for oil and gas production equipment and wells is calculated using the units of production method over proved developed oil and gas reserves. Provisions for impairment of undeveloped oil and gas leases are based on periodic evaluations and other factors. Depreciation of all other plant and equipment is determined on the straight-line method based on estimated useful lives.
	Capitalized Interest:  Interest from external borrowings is capitalized on material projects using the weighted average cost of outstanding borrowings until the project is substantially complete and ready for its intended use, which for oil and gas assets is at first production from the field. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying assets.
	Impairment of Long‑lived Assets:  The Corporation reviews long‑lived assets, including oil and gas fields, for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recovered.    If the carrying amounts of the long-lived assets are not expected to be recovered by estimated undiscounted future net cash flows, the assets are impaired and an impairment loss is recorded.  The amount of impairment is determined based on the estimated fair value of the assets generally determined by discounting anticipated future net cash flows, an income valuation approach, or by a market‑based valuation approach, which are Level 3 fair value measurements.  In the case of oil and gas fields, the present value of future net cash flows is based on management’s best estimate of future prices, which is determined with reference to recent historical prices and published forward prices, applied to projected production volumes and discounted at a risk-adjusted rate.  The projected production volumes represent reserves, including probable reserves, expected to be produced based on a projected amount of capital expenditures.  The production volumes, prices and timing of production are consistent with internal projections and other externally reported information.  Oil and gas prices used for determining asset impairments will generally differ from those used in the standardized measure of discounted future net cash flows, since the standardized measure requires the use of historical twelve month average prices.  As a result of the significant decline in crude oil prices in the fourth quarter of 2014, the Corporation tested its oil and gas properties for impairment and determined no impairment existed at December 31, 2014.
	Impairment of Goodwill:  The Corporation’s goodwill is tested for impairment annually on October 1st or when events or circumstances indicate that the carrying amount of the goodwill may not be recoverable based on a two-step process.  The goodwill test is conducted at a reporting unit level, which is defined in accounting standards as an operating segment or one level below an operating segment.  Following a reorganization of its management structure in 2013, the Corporation concluded that within its E&P segment it has two reporting units, offshore and onshore.  In step one of the impairment test, the fair value of a reporting unit is compared with its carrying amount, including goodwill.  If the fair value of the reporting unit exceeds its carrying value, goodwill is not impaired.  If the carrying value of the reporting unit exceeds its fair value, the Corporation performs step two to determine possible impairment by comparing the implied fair value of goodwill with the carrying amount.  If the implied fair value of goodwill is less than its carrying amount, an impairment loss would be recorded.   The Corporation performed a separate goodwill impairment test at December 31, 2014, and determined no impairment existed.
	Cash and Cash Equivalents:  Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have maturities of three months or less when acquired.
	Inventories:  Inventories are valued at the lower of cost or market. Cost is generally determined using average actual costs.  At December 31, 2013, refined petroleum product inventories associated with the now divested downstream businesses were valued at cost, using principally the last‑in, first‑out (LIFO) inventory method.
	Income Taxes:  Deferred income taxes are determined using the liability method.  The Corporation has net operating loss carryforwards or credit carryforwards in multiple jurisdictions and has recorded deferred tax assets for those losses and credits.  Additionally, the Corporation has deferred tax assets due to temporary differences between the book basis and tax basis of certain assets and liabilities.  Regular assessments are made as to the likelihood of those deferred tax assets being realized.  If it is more likely than not that some or all of the deferred tax assets will not be realized, a valuation allowance is recorded to reduce the deferred tax assets to the amount that is expected to be realized.  In evaluating the realizability of deferred tax assets, the Corporation considers the reversal of temporary differences, the expected utilization of net operating losses and credit carryforwards during available carryforward periods, the availability of tax planning strategies, the existence of appreciated assets and estimates of future taxable income and other factors.  In addition, the Corporation recognizes the financial statement effect of a tax position only when management believes that it is more likely than not, that based on the technical merits, the position will be sustained upon examination.  The Corporation does not provide for deferred U.S. income taxes for that portion of undistributed earnings of foreign subsidiaries that are indefinitely reinvested in foreign operations.  The Corporation classifies interest and penalties associated with uncertain tax positions as income tax expense.
	Asset Retirement Obligations:  The Corporation has material legal obligations to remove and dismantle long‑lived assets and to restore land or seabed at certain exploration and production locations. The Corporation recognizes a liability for the fair value of legally required asset retirement obligations associated with long‑lived assets in the period in which the retirement obligations are incurred. In addition, the fair value of any legally required conditional asset retirement obligations is recorded if the liability can be reasonably estimated. The Corporation capitalizes the associated asset retirement costs as part of the carrying amount of the long‑lived assets.
	Retirement Plans:  The Corporation recognizes the funded status of defined benefit postretirement plans in the Consolidated Balance Sheet. The funded status is measured as the difference between the fair value of plan assets and the projected benefit obligation. The Corporation recognizes the net changes in the funded status of these plans in the year in which such changes occur. Prior service costs and actuarial gains and losses in excess of 10% of the greater of the benefit obligation or the market value of assets are amortized over the average remaining service period of active employees.
	Derivatives:  The Corporation utilizes derivative instruments for both financial risk management and trading activities. In risk management activities, the Corporation may use futures, forwards, options and swaps, individually or in combination, to mitigate its exposure to fluctuations in prices of crude oil, natural gas, as well as changes in interest and foreign currency exchange rates. The Corporation, through a consolidated joint venture which is classified as held-for-sale at December 31, 2014, trades energy‑related commodities and derivatives including futures, forwards, options and swaps based on expectations of future market conditions.
	All derivative instruments are recorded at fair value in the Corporation’s Consolidated Balance Sheet. The Corporation’s policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized currently in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges) or hedges of firm commitments (fair value hedges). The effective portion of changes in fair value of derivatives that are designated as cash flow hedges is recorded as a component of other comprehensive income (loss) while the ineffective portion of the changes in fair value is recorded currently in earnings. Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings. Changes in fair value of derivatives designated as fair value hedges are recognized currently in earnings. The change in fair value of the related hedged commitment is recorded as an adjustment to its carrying amount and recognized currently in earnings.
	Fair value measurements:  The Corporation uses various valuation approaches in determining fair value for financial instruments, including the market and income approaches.  The Corporation’s fair value measurements also include non-performance risk and time value of money considerations.  Counterparty credit is considered for receivable balances, and the Corporation’s credit is considered for accrued liabilities.  The Corporation also records certain nonfinancial assets and liabilities at fair value when required by GAAP. These fair value measurements are recorded in connection with business combinations, qualifying nonmonetary exchanges, the initial recognition of asset retirement obligations and any impairment of long‑lived assets, equity method investments or goodwill.  The Corporation determines fair value in accordance with the fair value measurements accounting standard which established a hierarchy for the inputs used to measure fair value based on the source of the 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 is based on the lowest significant input level within this fair value hierarchy.
	Details on the methods and assumptions used to determine the fair values are as follows:
	Fair value measurements based on Level 1 inputs:  Measurements that are most observable are based on quoted prices of identical instruments obtained from the principal markets in which they are traded. Closing prices are both readily available and representative of fair value. Market transactions occur with sufficient frequency and volume to assure liquidity.
	Fair value measurements based on Level 2 inputs:  Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2. Measurements based on Level 2 inputs include over-the-counter derivative instruments that are priced on an exchange traded curve, but have contractual terms that are not identical to exchange traded contracts.
	Fair value measurements based on Level 3 inputs:  Measurements that are least observable are estimated from related market data, determined from sources with little or no market activity for comparable contracts or are positions with longer durations. Fair values determined using discounted cash flows and other unobservable data are also classified as Level 3.
	Share-based Compensation:  The fair value of all share‑based compensation is recognized as expense on a straight‑line basis over the full vesting period of the awards. The Corporation estimates the fair value of employee stock options at the date of grant using a Black‑Scholes valuation model, performance share units using a Monte Carlo simulation model, and restricted stock based on the market value of the underlying shares at the date of grant.
	Foreign Currency Translation:  The U.S. Dollar is the functional currency (primary currency in which business is conducted) for most foreign operations. Adjustments resulting from translating monetary assets and liabilities that are denominated in a currency other than the functional currency are recorded in Other, net in the Statement of Consolidated Income. For operations that do not use the U.S. Dollar as the functional currency, primarily those in Norway where the Norwegian Krone is used, adjustments resulting from translating foreign currency assets and liabilities into U.S. Dollars are recorded in the Consolidated Balance Sheet in a separate component of equity titled Accumulated other comprehensive income (loss).
	Maintenance and Repairs:  Maintenance and repairs are expensed as incurred. Capital improvements are recorded as additions in Property, plant and equipment.
	Environmental Expenditures:  The Corporation accrues and expenses the undiscounted environmental costs necessary to remediate existing conditions related to past operations when the future costs are probable and reasonably estimable. At year‑end 2014, the Corporation’s reserve for estimated remediation liabilities was approximately $80 million and was included within accrued liabilities.  Environmental expenditures that increase the life or efficiency of property or reduce or prevent future adverse impacts to the environment are capitalized.
	New Accounting Pronouncements:  In April 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The ASU amends the criteria for reporting discontinued operations to include only disposals representing a strategic shift in operations. The ASU also requires expanded disclosures regarding the assets, liabilities, income, and expenses of discontinued operations. This ASU is effective for the Corporation in the first quarter of 2015 and early adoption is permitted. The Corporation did not elect early adoption of this ASU and does not expect adoption to have a significant impact on its consolidated financial statements.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, as a new Accounting Standards Codification (ASC) Topic ASC 606. This ASU is effective for the Corporation beginning in the first quarter of 2017 and early adoption is not permitted. The Corporation is currently assessing the impact of the ASU on its consolidated financial statements.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Discontinued Operations And Disposal Groups [Abstract]
Discontinued Operations
	2. Discontinued Operations
	The results of operations for the Corporation’s divested retail, energy marketing and terminal operations, the Port Reading refining facility which ceased operations in 2013, and the energy trading joint venture, HETCO, which was classified as held for sale at December 31, 2014, have been reported as discontinued operations in the Statement of Consolidated Income for all periods presented.  These businesses were previously included in the M&R segment.
	Sales and other operating revenues and Income from discontinued operations were as follows:
			2014		2013		2012
			(In millions)
	Sales and other operating revenues		$	9,576	$	22,652	$	25,517
	Income from discontinued operations before income taxes		$	1,071	$	1,835	$	400
	Current tax provision (benefit)*			—		—		7
	Deferred tax provision (benefit)			389		649		138
	Provision for income taxes			389		649		145
	Income (loss) from discontinued operations, net of income taxes		$	682	$	1,186	$	255
	Less: Net income (loss) attributable to noncontrolling interests			57		-6		20
	Income from discontinued operations attributable to Hess Corporation		$	625	$	1,192	$	235
	*	Substantially all current tax expense relates to foreign taxes on energy trading operations.
	2014:  In September, the Corporation completed the sale of its retail business for cash proceeds of approximately $2.8 billion. This transaction resulted in a pre-tax gain of $954 million ($602 million after income taxes) after deducting the net book value of assets, including $115 million of goodwill. During the year, the Corporation recorded pre-tax gains of $275 million ($171 million after income taxes) relating to the liquidation of last-in, first-out (LIFO) inventories associated with the divested downstream operations. In addition, the Corporation recorded pre-tax charges totaling $308 million ($202 million after income taxes) for impairments, environmental matters, severance and exit related activities associated with the divestiture of downstream operations. The Corporation also recognized a pre-tax charge of $115 million ($72 million after income taxes) related to the termination of lease contracts and the purchase of 180 retail gasoline stations in preparation for the sale of the retail operations. In January, the Corporation’s retail business acquired its partners’ 56% interest in WilcoHess, a retail gasoline joint venture, for approximately $290 million and the settlement of liabilities. In connection with this business combination, the Corporation recorded a pre-tax gain of $39 million ($24 million after income taxes) to remeasure the carrying value of the Corporation’s original 44% equity interest in WilcoHess to fair value, including recognition of goodwill in the amount of $115 million. Effective from the acquisition date, the Corporation consolidated the results of WilcoHess’ operations, which have been included in the results of discontinued operations reported above. The assets and liabilities acquired from WilcoHess were included in the sale of the retail business in September 2014.
	2013: In December, the Corporation sold its U.S. East Coast terminal network, St. Lucia terminal and related businesses for cash proceeds of approximately $1.0 billion. The transaction resulted in a pre-tax gain of $739 million ($531 million after income taxes). In November, the Corporation sold its energy marketing business for cash proceeds of approximately $1.2 billion, which resulted in a pre-tax gain of $761 million ($464 million after income taxes). During the year the Corporation recognized pre-tax gains of $678 million ($414 million after income taxes) relating to the liquidation of LIFO inventories.  In addition, the Corporation recorded pre-tax charges totaling $523 million ($334 million after income taxes) for impairments, severance, Port Reading refinery shutdown costs, environmental matters, and exit related activities associated with the divestiture of downstream operations.
	2012: In 2012, the Corporation recorded pre-tax income of $165 million ($104 million after income taxes) from the partial liquidation of LIFO inventories. The Corporation also recorded pre-tax charges totaling $43 million ($33 million after income taxes) for asset impairments to certain marketing properties and other charges.

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Dispositions
	3.  Dispositions
	2014: In January, the Corporation completed the sale of its interest in the Pangkah asset, offshore Indonesia for cash proceeds of approximately $650 million.  This transaction resulted in a pre-tax gain of $31 million ($10 million loss after income taxes) after deducting the net book value of assets, including allocated goodwill of $56 million.  In April, the Corporation completed the sale of its interests in Thailand for cash proceeds of approximately $805 million.  This transaction resulted in a pre-tax gain of $706 million ($706 million after income taxes) after deducting the net book value of assets, including allocated goodwill of $76 million.  In the first six months of 2014, the Corporation completed, through multiple transactions, the sale of approximately 77,000 net acres in the dry gas area of the Utica shale play including related wells and facilities, for total cash proceeds of approximately $1,075 million and recorded a pre-tax gain of $62 million ($35 million gain after income taxes) after deducting the net book value of assets, including allocated goodwill of $11 million.  In June, the Corporation completed the sale of its joint venture interest in an electric generating facility in Newark, New Jersey for cash proceeds of $320 million, resulting in a pre-tax gain of approximately $13 million ($8 million after income taxes). In September, the Corporation sold its joint venture interest in the Bayonne Energy Center (BEC) for $79 million.  In the first quarter of 2014, the Corporation recorded a charge of $84 million ($52 million after income taxes) to reduce to fair value its investment in BEC.  In September, the Corporation completed the sale of its interest in an exploration asset in the United Kingdom North Sea for $53 million which resulted in a pre-tax gain of $33 million ($33 million after income taxes).
	2013:  In January, the Corporation completed the sale of its interests in the Beryl fields and the Scottish Area Gas Evacuation System (SAGE) in the UK North Sea for cash proceeds of $442 million.  The transaction resulted in a pre‑tax gain of $328 million ($323 million after income taxes), after deducting the net book value of assets including allocated goodwill of $48 million.  In March, the Corporation sold its interests in the Azeri‑Chirag‑Guneshli (ACG) fields (Hess 3%), offshore Azerbaijan in the Caspian Sea, and the associated Baku‑Tbilisi‑Ceyhan (BTC) oil transportation pipeline company (Hess 2%) for cash proceeds of $884 million.  The transaction resulted in a pre‑tax gain of $360 million ($360 million after income taxes), after deducting the net book value of assets including allocated goodwill of $52 million.  In April, the Corporation completed the sale of its Russian subsidiary, Samara-Nafta, for cash proceeds of $2.1 billion after working capital and other adjustments, including allocated goodwill of $148 million. Based on the Corporation’s 90% interest in Samara-Nafta, after-tax proceeds to Hess were approximately $1.9 billion. This transaction resulted in a pre-tax gain of $1,119 million ($1,119 million after income taxes), which was reduced by $168 million for the noncontrolling interest holder’s share of the gain, resulting in a net gain attributable to the Corporation of $951 million.  In December, the Corporation completed the sale of its interest in the Natuna A Field, offshore Indonesia for total cash proceeds of approximately $656 million.  The transaction resulted in a pre‑tax gain of $388 million ($343 million after income taxes), after deducting the net book value of assets including allocated goodwill of $39 million.
	2012:  In January, the Corporation completed the sale of its interest in the Snohvit Field (Hess 3%), a liquefied natural gas project, offshore Norway, for cash proceeds of $132 million.  The transaction resulted in a pre-tax gain of $36 million ($36 million after income taxes), after deducting the net book value of assets including allocated goodwill of $14 million.  In September, the Corporation completed the sale of its interests in the Schiehallion Field (Hess 16%) in the UK 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.  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.  In October, the Corporation completed the sale of its interests in the Bittern Field (Hess 28%) in the UK North Sea and the associated Triton floating production, storage and offloading vessel for cash proceeds of $187 million.  The transaction resulted in a pre-tax gain of $172 million ($172 million after income taxes) after deducting the net book value of assets including allocated goodwill of $12 million.

Exit_and_Disposal_Costs

Exit and Disposal Costs	12 Months Ended
	Dec. 31, 2014
Restructuring And Related Activities [Abstract]
Exit and Disposal Costs	4. Exit and Disposal Costs
	The following table provides the components of and changes in the Corporation’s restructuring accruals:
		Exploration			Corporate, Interest
		and			and			Discontinued
		Production			Other			Operations			Total
		(In millions)
	Employee Severance
	Balance at January 1, 2014	$	32		$	26		$	113		$	171
	Provision		19			16			41			76
	Payments		(35	)		(26	)		(109	)		(170	)
	Balance at December 31, 2014		16			16			45			77
	Facility and Other Exit Costs
	Balance at January 1, 2014		53			17			48			118
	Provision		(15	)		10			70			65
	Payments, settlements and other		(38	)		(12	)		(108	)		(158	)
	Balance at December 31, 2014		—			15			10			25
	Total restructuring accruals at December 31, 2014	$	16		$	31		$	55		$	102
	The following table provides the financial statement classification of costs and expenses associated with the Corporation’s restructuring program:
		2014			2013
		(In millions)
	Employee Severance
	Operating costs and expenses	$	5		$	22
	Exploration expenses, including dry holes and lease impairment		3			19
	General and administrative expenses		27			63
	Income from discontinued operations		41			148
	Total employee severance	$	76		$	252
	Facility and Other Exit Costs
	Other, net	$	—		$	8
	Operating costs and expenses		—			1
	General and administrative expenses		(2	)		54
	Depreciation, depletion and amortization		(3	)		16
	Income from discontinued operations		70			141
	Total facility and other exit costs	$	65		$	220
	The employee severance charges primarily resulted from the Corporation’s divestiture program announced in March 2013. The severance charges were based on probable amounts incurred under ongoing severance arrangements or other statutory requirements, plus amounts earned under enhanced benefit arrangements. The expense associated with the enhanced benefits was recognized ratably over the estimated service period required for the employee to earn the benefit upon termination.
	The facility and other exit costs relate to charges associated with the cessation of use of certain leased office space, contract terminations and professional fees associated with the divestitures as well as costs associated with the shutdown of Port Reading refining operations.
	For the accrued employee severance at December 31, 2014 totaling $77 million, the Corporation expects to pay approximately 95% in 2015 and the remainder in 2016. For the accrued facility and other exit costs totaling $25 million, the Corporation expects to pay approximately 45% in 2015 and the remainder in 2016 and beyond.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventories	5. Inventories
	Inventories at December 31 were as follows:
		2014		2013
		(In millions)
	Crude oil	$	246	$	291
	Natural gas and refined petroleum products		—		618
	Less: LIFO adjustment		—		(339	)
			246		570
	Materials , supplies and merchandise		281		384
	Total inventories	$	527	$	954
	Inventories related to the downstream businesses, consisting primarily of refined petroleum products and merchandise, were $355 million at December 31, 2013.  The percentage of LIFO inventories to total crude oil, refined petroleum products and natural gas inventories was 43% at December 31, 2013.  See also Note 2, Discontinued Operations.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2014
Property Plant And Equipment [Abstract]
Property, Plant and Equipment	6. Property, Plant and Equipment
	Property, plant and equipment at December 31 were as follows:
			2014			2013
			(In millions)
	Exploration and Production
	Unproved properties		$	1,468		$	2,460
	Proved properties			4,211			4,121
	Wells, equipment and related facilities			40,649			37,274
				46,328			43,855
	Corporate, Interest and Other			194			2,095
	Total — at cost			46,522			45,950
	Less: Reserves for depreciation, depletion, amortization and lease impairment			19,005			17,179
	Property, plant and equipment — net*		$	27,517		$	28,771
	*	At December 31, 2013, Corporate, Interest and Other included $1,021 million of property, plant and equipment, net related to the divested Retail Marketing operations.
	Assets Held for Sale:  At December 31, 2014, assets totaling $1,035 million, which consisted of accounts receivable and other long-lived assets, related to the Corporation’s interest in HETCO, are reported in Other current assets in the Consolidated Balance Sheet.  In addition, liabilities totaling $797 million, which consisted primarily of accounts payable, were reported in Accrued Liabilities.  See Note 22, Subsequent Events.
	At December 31, 2013, E&P assets totaling $1,097 million, primarily consisting of the net property, plant and equipment balances as well as allocated goodwill of $76 million, for the Corporation’s assets in Thailand and the Pangkah Field, offshore Indonesia (Hess 75%) were classified as held for sale and are reported within Other current assets in the Consolidated Balance Sheet. In addition, liabilities related to these properties totaling $286 million, primarily consisting of asset retirement obligations and deferred income taxes, are reported within Accrued liabilities.  In 2014, the Corporation completed the sale of its interests in Thailand and Pangkah.
	Capitalized Exploratory Well Costs:  The following table discloses the amount of capitalized exploratory well costs pending determination of proved reserves at December 31, and the changes therein during the respective years:
			2014			2013			2012
			(In millions)
	Beginning balance at January 1		$	2,045		$	2,259		$	2,022
	Additions to capitalized exploratory well costs pending the determination of proved reserves			292			237			407
	Reclassifications to wells, facilities and equipment based on the determination of proved reserves			(629	)		(106	)		(41	)
	Capitalized exploratory well costs charged to expense			(235	)		(267	)		(129	)
	Dispositions and other			(57	)		(78	)		—
	Ending balance at December 31		$	1,416		$	2,045		$	2,259
	Number of wells at end of year			37			50			68
	In 2014, reclassifications to wells, facilities and equipment based on the determination of proved reserves primarily related to the Stampede project in the Gulf of Mexico, which the co-owners sanctioned for development. Capitalized exploratory well costs charged to expense in 2014 included $169 million to write-off a previously capitalized exploration well in Green Canyon Block 469 in the Gulf of Mexico.  In 2013, reclassifications to wells, facilities and equipment based on the determination of proved reserves primarily related to the Shenzi project in the Gulf of Mexico. Capitalized exploratory well costs charged to expense in 2013 included $260 million to write-off two previously capitalized exploration wells in Area 54, offshore Libya, due to civil unrest in the country. The preceding table excludes exploratory dry hole costs of $66 million, $77 million and $248 million in 2014, 2013 and 2012, respectively, which were incurred and subsequently expensed in the same year.
	At December 31, 2014, exploratory drilling costs capitalized in excess of one year past the indicated year of completion of drilling were as follows (in millions):
	2013		$	74
	2012			373
	2011			338
	2010			211
	2009 and prior			236
			$	1,232
	Capitalized exploratory well costs greater than one year old after completion of drilling were $1,232 million at December 31, 2014. Approximately 68% of the capitalized well costs in excess of one year relates to Block WA-390-P, offshore Western Australia, where development planning and commercial activities for the Corporation’s natural gas discoveries are ongoing.  In December 2014, the Corporation executed a non-binding letter of intent with the North West Shelf (NWS), a third party joint venture with existing natural gas processing and liquefaction facilities.  Successful execution of binding agreements with NWS is necessary before the Corporation can execute a gas sales agreement and sanction development of the project. Approximately 30% relates to offshore Ghana where the Corporation has drilled seven successful exploration wells. Appraisal plans for the seven wells on the block were submitted to the Ghanaian government in June 2013 for approval. Four of the plans were approved and discussions continue with the government on the three remaining appraisal plans. In the third quarter of 2014, the Corporation completed a three well appraisal program in Ghana. Well results are being evaluated and development planning is progressing. The remaining 2% 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.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill	7. Goodwill
	The changes in the carrying amount of goodwill are as follows:
			2014			2013
			(In millions)
	Beginning balance at January 1		$	1,869		$	2,208
	Acquisitions			115			—
	Dispositions*			(126	)		(339	)
	Ending balance at December 31		$	1,858		$	1,869
	*	In 2013, the dispositions include $21 million allocated to other assets sold and $76 million that was classified as held for sale and reported within Other current assets.
	The increase in goodwill in 2014 resulted from the Corporation’s acquisition of WilcoHess, which was subsequently disposed of as part of the sale of the Corporation’s retail marketing operations. See Note 2, Discontinued Operations, in the Notes to the Consolidated Financial Statements.

Asset_Impairments

Asset Impairments	12 Months Ended
	Dec. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]
Asset Impairments	8. Asset Impairments
	In 2013, the Corporation announced the sale of its E&P assets in Indonesia for approximately $1.3 billion.  The sale was executed in two separate transactions, with Natuna A completing in December 2013 and Pangkah in January 2014, as a result of a partner exercising their preemptive rights.  Based on the sales proceeds for each transaction, results of operations for 2013 included a pre‑tax gain on sale related to Natuna A of $388 million ($343 million after income taxes), and a pre‑tax asset impairment charge of $289 million ($187 million after income taxes) to adjust the carrying value of the Pangkah assets to their fair value at December 31, 2013.
	During 2012, the Corporation recorded E&P asset impairment charges totaling $582 million ($344 million after income taxes). These impairment charges consisted of $374 million ($228 million after income taxes) associated with the divestiture of assets in the Eagle Ford Shale in Texas and $208 million ($116 million after income taxes) related to non‑producing properties in the UK North Sea.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	9. Asset Retirement Obligations
	The following table describes changes to the Corporation’s asset retirement obligations:
		2014			2013
		(In millions)
	Asset retirement obligations at January 1	$	2,772		$	2,661
	Liabilities incurred		63			42
	Liabilities settled or disposed of		(420	)		(576	)
	Accretion expense		136			129
	Revisions of estimated liabilities		263			573
	Foreign currency translation		(91	)		(57	)
	Asset retirement obligations at December 31		2,723			2,772
	Less: Current obligations		442			523
	Long-term obligations at December 31	$	2,281		$	2,249
	The revisions in 2014 and 2013 primarily reflect changes in the expected scope of operations and updates to service and equipment costs.  The 2013 revision also reflects increases in the time expected to complete dismantlement activities.

Debt_and_Interest_Expense

Debt and Interest Expense	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt and Interest Expense	10. Debt and Interest Expense
	Long‑term debt at December 31 consisted of the following:
			2014		2013
			(In millions)
	Fixed-rate public notes:
	7.0% due 2014		$	—	$	250
	1.3% due 2017			300		—
	8.1% due 2019			999		998
	3.5% due 2024			298		—
	7.9% due 2029			696		695
	7.3% due 2031			747		747
	7.1% due 2033			598		598
	6.0% due 2040			745		745
	5.6% due 2041			1,242		1,242
	Total fixed-rate public notes			5,625		5,275
	Financing obligations associated with floating production system			331		296
	Other fixed-rate notes, weighted average rate 12.9%			—		135
	Project lease financing, weighted average rate 5.1%			—		60
	Fair value adjustments - interest rate hedging			31		30
	Other debt			—		2
	Total debt			5,987		5,798
	Less: Short-term debt and current maturities of long-term debt			68		378
	Total long-term debt		$	5,919	$	5,420
	At December 31, 2014, the Corporation had a $4 billion syndicated revolving credit facility that is unused and has a maturity date of April 2016. This facility can be used for borrowings and letters of credit. Borrowings on the facility bear interest at 1.25% above the London Interbank Offered Rate. A fee of 0.25% per annum is also payable on the amount of the facility. The interest rate and facility fee are subject to adjustment if the Corporation’s credit rating changes. In January 2015, the Corporation entered into a new five-year credit agreement that replaces the previous agreement.  See Note 22, Subsequent Events.
	In June 2014, the Corporation issued $600 million of unsecured, fixed-rate notes ($598 million net of discount) comprising $300 million with a coupon of 1.3% and scheduled to mature in June 2017 as well as $300 million with a coupon of 3.5% and scheduled to mature in July 2024. In 2014, the Corporation repaid $590 million of debt, including $250 million of unsecured, fixed-rate notes, $249 million for the payment of various lease obligations primarily to retire retail gasoline station leases and $74 million assumed in the acquisition of WilcoHess.
	During 2013, the Corporation repaid a net amount of $2,348 million under available credit facilities, which consisted of $758 million from its syndicated revolving credit facility, $990 million from the Corporation’s short-term credit facilities and $600 million from its asset-backed credit facility. The Corporation recorded capital lease obligations totaling $98 million in conjunction with its commitment to acquire 50 existing Hess retail gasoline stations that were previously held under operating leases. The Corporation repaid $136 million of other debt in 2013.
	The Corporation recorded a non-cash net increase in debt of $68 million in 2014 and $116 million in 2013 related to progress on construction of a floating production system for the Tubular Bells Field, which commenced production in the fourth quarter of 2014.
	At December 31, 2014, the Corporation’s fixed rate public notes have a principal amount of $5,650 million ($5,625 million net of unamortized discount). Interest rates on the outstanding fixed rate public notes have a weighted average rate of 6.4%.
	The aggregate long‑term debt maturing during the next five years is as follows (in millions): 2015—$68; 2016—$71; 2017—$373; 2018—$78 and 2019—$1,070.
	The Corporation’s long‑term debt agreements, including the revolving credit facility, contain financial covenants that restrict the amount of total borrowings and secured debt.  The most restrictive of these covenants allow the Corporation to borrow up to an additional $5.6 billion of secured debt at December 31, 2014.
	Outstanding letters of credit at December 31 were as follows:
			2014		2013
			(In millions)
	Committed lines*		$	25	$	274
	Uncommitted lines*			372		136
	Total		$	397	$	410
	*	Committed and uncommitted lines have expiration dates through 2016.
	Of the $397 million of letters of credit outstanding at December 31, 2014, $54 million relates to contingent liabilities and the remaining $343 million relates to liabilities recorded in the Consolidated Balance Sheet.
	The total amount of interest paid (net of amounts capitalized) was $326 million, $408 million and $419 million in 2014, 2013 and 2012, respectively. The Corporation capitalized interest of $76 million, $60 million and $28 million in 2014, 2013 and 2012, respectively.

Sharebased_Compensation

Share-based Compensation	12 Months Ended
	Dec. 31, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-based Compensation	11. Share-based Compensation
	The Corporation granted restricted common shares, performance share units (PSUs) and stock options to employees under its 2008 Long‑term Incentive Plan (LTIP), as amended.  Outstanding restricted stock and PSUs generally vest three years from the date of grant.  Outstanding stock options vest over three years from the date of grant and have a 10‑year term and an exercise price equal to the market price on the date of grant.
	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 peer companies over a three‑year performance period ending December 31 of the year prior to settlement of the grant. Payouts of the 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, but will only be paid out on earned shares after the performance period.
	Share‑based compensation expense consisted of the following:
			Before Income Taxes										After Income Taxes
			2014			2013				2012			2014		2013			2012
			(In millions)
	Restricted stock		$	62		$	31			$	57		$	39	$	19		$	35
	Stock options			2			13				34			1		8			21
	Performance share units			19			10				8			12		6			5
	Total*		$	83		$	54			$	99		$	52	$	33		$	61
	*	Includes pre‑tax share‑based compensation expense included in Income from continuing operations of approximately $87 million, $60 million and $83 million for 2014, 2013 and 2012, respectively.
	The Corporation reversed share‑based compensation expenses totaling $33 million ($25 million for restricted stock, $7 million for PSUs and $1 million for stock options) in 2013 for grants that were not expected to vest as a result of the Corporation’s transformation to a pure play E&P company.
	Based on share‑based compensation awards outstanding at December 31, 2014, unearned compensation expense, before income taxes, will be recognized in future years as follows (in millions): 2015—$66, 2016—$39 and 2017—$7.
	The Corporation’s share‑based compensation activity consisted of the following:
			Performance Share Units							Stock Options					Restricted Stock
			Performance			Weighted-				Options			Weighted-		Shares of			Weighted-
			Share Units			Average Fair							Average		Restricted			Average Price
						Value on Date							Exercise Price		Common			on Date of
						of Grant							per Share		Stock			Grant
			(In thousands)							(In thousands)					(In thousands)
	Outstanding at January 1, 2014			635		$	89.45				10,141		$	63.08		2,865		$	69.36
	Granted			298			90.32				163			80.35		1081			81.2
	Exercised			—			—				(3,327	)		54.99		—			—
	Vested			—			—				—			—		(510	)		82.42
	Forfeited			(133	)		88.6				(211	)		85.07		(535	)		68.74
	Outstanding at December 31, 2014			800		$	89.91				6,766		$	66.79		2,901		$	71.58
	The table below summarizes information regarding the outstanding and exercisable stock options as of December 31, 2014:
				Outstanding Options								Exercisable Options
				Options		Weighted-Average Remaining Contractual Life			Weighted-Average Exercise Price per Share			Options		Weighted-Average Exercise Price per Share
	Range of Exercise Prices
				(In thousands)		(Years)						(In thousands)
	$20.00 – $40.00			65		1			$         29.96			65	$	29.96
	$40.01 – $50.00			684		2			49.42			681		49.44
	$50.01 – $60.00			1,927		4			55.08			1,921		55.08
	$60.01 – $80.00			1,302		4			60.68			1,302		60.68
	$80.01 – $120.00			2,788		5			82.85			2,625		83.00
				6,766		4			$         66.79			6,594	$	66.47
	The following weighted average assumptions were utilized to estimate the fair value of PSU awards:
			2014			2013
	Risk free interest rate			0.65	%		0.36	%
	Stock price volatility			0.359			0.359
	Contractual term in years			3			3
	Grant date price of Hess common stock		$	80.35		$	69.49
	The risk free interest rate is based on the vesting period of the award and is obtained from published sources. The stock price volatility is determined from the historical stock prices of the peer group using the vesting period. The contractual term is equivalent to the vesting period.
	Restricted common shares are valued based on the prevailing market price of the Corporation’s common stock on the date of grant.
	In May 2008, shareholders approved the 2008 LTIP, which was amended in May 2010 and May 2012 to increase the number of new shares of common stock available for awards. At December 31, 2014, the Corporation had 8.5 million shares that remain available for issuance under the 2008 LTIP, as amended, out of the total of 29.0 million shares of common stock authorized for issuance under the 2008 LTIP, as amended.

Foreign_Currency

Foreign Currency	12 Months Ended
	Dec. 31, 2014
Foreign Currency [Abstract]
Foreign Currency	12. Foreign Currency
	Foreign currency gains (losses) before income taxes recorded in Other, net in the Statement of Consolidated Income amounted to a loss of $43 million in 2014, a loss of $54 million in 2013 and a gain of $36 million in 2012, all of which related to the Corporation’s continuing operations. The after‑tax foreign currency translation adjustments included in Accumulated other comprehensive income (loss) totaled $(757) million at December 31, 2014 and $(1) million at December 31, 2013.  The change in 2014 related to the Corporation’s Norwegian operations and reflects translation impacts of the strengthening U.S. dollar versus the Norwegian Krone.

Retirement_Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2014
Compensation And Retirement Disclosure [Abstract]
Retirement Plans	13. Retirement Plans
	The Corporation has funded noncontributory defined benefit pension plans for a significant portion of its employees. In addition, the Corporation has an unfunded supplemental pension plan covering certain employees, which provides incremental payments that would have been payable from the Corporation’s principal pension plans, were it not for limitations imposed by income tax regulations. The plans provide defined benefits based on years of service and final average salary. Additionally, the Corporation maintains an unfunded postretirement medical plan that provides health benefits to certain qualified retirees from ages 55 through 65. The measurement date for all retirement plans is December 31.
	The following table summarizes the Corporation’s benefit obligations and the fair value of plan assets and shows the funded status of the pension and postretirement medical plans:
			Funded						Unfunded						Postretirement
			Pension Plans						Pension Plan						Medical Plan
			2014			2013			2014			2013			2014			2013
			(In millions)
	Change in benefit obligation
	Balance at January 1		$	1,957		$	2,110		$	253		$	234		$	97		$	134
	Service cost			45			61			12			12			4			4
	Interest cost			91			82			9			7			3			3
	Actuarial (gain) loss (a)			470			(139	)		61			28			(4	)		(4	)
	Benefit payments (b)			(77	)		(69	)		(57	)		(20	)		(6	)		(5	)
	Plan curtailments (c)			(3	)		(103	)		—			(8	)		—			(35	)
	Special termination benefits			2			5			—			—			—			—
	Foreign currency exchange rate changes			(35	)		10			—			—			—			—
	Balance at December 31			2,450			1,957			278			253			94			97
	Change in fair value of plan assets
	Balance at January 1			2,145			1,763			—			—			—			—
	Actual return on plan assets			151			292			—			—			—			—
	Employer contributions			68			146			56			20			6			5
	Benefit payments (b)			(77	)		(69	)		(56	)		(20	)		(6	)		(5	)
	Foreign currency exchange rate changes			(36	)		13			—			—			—			—
	Balance at December 31			2,251			2,145			—			—			—			—
	Funded status (plan assets greater (less) than benefit obligations) at December 31			(199	)		188			(278	)		(253	)		(94	)		(97	)
	Unrecognized net actuarial (gains) losses			859			405			135			108			(5	)		(2	)
	(a)	The change in discount rate and mortality assumptions in 2014 resulted in total actuarial losses of approximately $330 million and $125 million, respectively.
	(b)	Benefit payments include lump-sum settlement payments of $55 million in 2014.
	(c)	During the first quarter of 2013, the Corporation’s pension and other postretirement plans were impacted by a significant reduction in the expected future service from active participants due to the Corporation’s announced asset sales program.
	Amounts recognized in the Consolidated Balance Sheet at December 31 consisted of the following:
			Funded						Unfunded						Postretirement
			Pension Plans						Pension Plan						Medical Plan
			2014			2013			2014			2013			2014			2013
			(In millions)
	Pension asset / (accrued benefit liability)		$	(199	)	$	188		$	(278	)	$	(253	)	$	(94	)	$	(97	)
	Accumulated other comprehensive loss, pre-tax*			859			405			135			108			(5	)		(2	)
	*	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) for these retirement plans was $652 million at December 31, 2014 and $342 million at December 31, 2013.
	The accumulated benefit obligation for the funded defined benefit pension plans was $2,325 million at December 31, 2014 and $1,873 million at December 31, 2013.  The accumulated benefit obligation for the unfunded defined benefit pension plan was $214 million at December 31, 2014 and $222 million at December 31, 2013.
	Components of net periodic benefit cost for funded and unfunded pension plans and the postretirement medical plan consisted of the following:
			Pension Plans									Postretirement Medical Plan
			2014			2013			2012			2014			2013			2012
			(In millions)
	Service cost		$	57		$	73		$	74		$	4		$	4		$	7
	Interest cost			100			89			88			3			3			5
	Expected return on plan assets			(161	)		(141	)		(116	)		—			—			—
	Amortization of unrecognized net actuarial losses			31			61			83			—			1			2
	Settlement loss			24			—			9			—			—			—
	Curtailment loss			—			1			—			—			—			—
	Special termination benefit recognized			1			5			—			—			—			—
	Net periodic benefit cost		$	52		$	88		$	138		$	7		$	8		$	14
	The Corporation’s 2015 pension and postretirement medical expense is estimated to be approximately $80 million, which includes approximately $75 million related to the amortization of unrecognized net actuarial losses.
	The weighted average actuarial assumptions used by the Corporation’s funded and unfunded pension plans were as follows:
			2014			2013			2012
	Weighted average assumptions used to determine benefit obligations at December 31
	Discount rate			3.8	%		4.6	%		3.8	%
	Rate of compensation increase			5			4.4			4.3
	Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31
	Discount rate			4.6			4			4.3
	Expected return on plan assets			7.5			7.5			7.5
	Rate of compensation increase			4.4			4.3			4.3
	The actuarial assumptions used by the Corporation’s postretirement medical plan were as follows:
			2014			2013			2012
	Assumptions used to determine benefit obligations at December 31
	Discount rate			3.1	%		3.6	%		3.1	%
Initial health care trend rate			6.8	%		7.1	%		7.3	%
Ultimate trend rate			4.5	%		4.6	%		4.8	%
Year in which ultimate trend rate is reached			2029			2027			2022
The assumptions used to determine net periodic benefit cost for each year were established at the end of each previous year while the assumptions used to determine benefit obligations were established at each year‑end. The net periodic benefit cost and the actuarial present value of benefit obligations are based on actuarial assumptions that are reviewed on an annual basis. The discount rate is developed based on a portfolio of high‑quality, fixed income debt instruments with maturities that approximate the expected payment of plan obligations. The overall expected return on plan assets is developed from the expected future returns for each asset category, weighted by the target allocation of pension assets to that asset category.
The Corporation’s investment strategy is to maximize long‑term returns at an acceptable level of risk through broad diversification of plan assets in a variety of asset classes. Asset classes and target allocations are determined by the Corporation’s investment committee and include domestic and foreign equities, fixed income, and other investments, including hedge funds, real estate and private equity. Investment managers are prohibited from investing in securities issued by the Corporation unless indirectly held as part of an index strategy. The majority of plan assets are highly liquid, providing ample liquidity for benefit payment requirements. The current target allocations for plan assets are 50% equity securities, 25% fixed income securities (including cash and short‑term investment funds) and 25% to all other types of investments. Asset allocations are rebalanced on a periodic basis throughout the year to bring assets to within an acceptable range of target levels.
The following tables provide the fair value of the financial assets of the funded pension plans as of December 31, 2014 and 2013 in accordance with the fair value measurement hierarchy described in Note 1, Summary of Significant Accounting Policies in the Notes to the Consolidated Financial Statements:
		Level 1			Level 2			Level 3			Total
		(In millions)
December 31, 2014
Cash and short-term investment funds		$	6		$	47		$	—		$	53
Equities:
U.S. equities (domestic)			719			—			—			719
International equities (non-U.S.)			72			177			—			249
Global equities (domestic and non-U.S.)			10			218			—			228
Fixed income:
Treasury and government issued (a)			—			222						222
Government related (b)			—			7			1			8
Mortgage-backed securities (c)			—			147			1			148
Corporate			3			137						140
Other:
Hedge funds			—			—			302			302
Private equity funds			—			—			105			105
Real estate funds			12			—			48			60
Diversified commodities funds			—			17			—			17
		$	822		$	972		$	457		$	2,251
December 31, 2013
Cash and short-term investment funds		$	3		$	72		$	—		$	75
Equities:
U.S. equities (domestic)			729			—			—			729
International equities (non-U.S.)			81			171			—			252
Global equities (domestic and non-U.S.)			8			208			—			216
Fixed income:
Treasury and government issued (a)			—			169			1			170
Government related (b)			—			9			—			9
Mortgage-backed securities (c)			—			109			1			110
Corporate			2			124			1			127
Other:
Hedge funds			—			—			291			291
Private equity funds			—			—			89			89
Real estate funds			10			—			47			57
Diversified commodities funds			—			20			—			20
		$	833		$	882		$	430		$	2,145
(a)	Includes securities issued and guaranteed by U.S. and non‑U.S. governments.
(b)	Primarily consists of securities issued by governmental agencies and municipalities.
(c)	Comprised of U.S. residential and commercial mortgage-backed securities.
Cash and short‑term investment funds consist of cash on hand and short-term investment funds that provide for daily investments and redemptions and are valued and carried at a $1 net asset value (NAV) per fund share. Cash on hand is classified as Level 1 and short‑term investment funds are classified as Level 2.
Equities consist of equity securities issued by U.S. and non‑U.S. corporations as well as commingled investment funds that invest in equity securities. Individually held equity securities, which are traded actively on exchanges and have readily available price quotes, are classified as Level 1. Commingled fund values, which are valued at the NAV per fund share derived from the quoted prices in active markets of the underlying securities, are classified as Level 2.
Fixed income investments consist of securities issued by the U.S. government, non‑U.S. governments, governmental agencies, municipalities and corporations, and agency and non-agency mortgage‑backed securities. This investment category also includes commingled investment funds that invest in fixed income securities. Individual fixed income securities are generally priced on the basis of evaluated prices from independent pricing services, which are monitored and provided by the third-party custodial firm responsible for safekeeping plan assets. Individual fixed income securities are classified as Level 2 or 3. Fixed income commingled fund values, which reflect the NAV per fund share derived indirectly from observable inputs or from quoted prices in less liquid markets of the underlying securities, are classified as Level 2.
Other investments consist of exchange‑traded real estate investment trust securities, as well as commingled fund and limited partnership investments in hedge funds, private equity, real estate and diversified commodities. Exchange‑traded securities are classified as Level 1. Commingled fund values reflect the NAV per fund share and are classified as Level 2 or 3. Private equity and real estate limited partnership values reflect information reported by the fund managers, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data and independent appraisals from third‑party sources with professional qualifications. Hedge funds, private equity and non‑exchange‑traded real estate investments are classified as Level 3.
The following tables provide changes in financial assets that are measured at fair value based on Level 3 inputs that are held by institutional funds classified as:
								Private			Real
		Fixed			Hedge			Equity			Estate
		Income*			Funds			Funds			Funds			Total
		(In millions)
Balance at January 1, 2013		$	2		$	255		$	75		$	45		$	377
Actual return on plan assets			—			26			11			2			39
Purchases, sales or other settlements			1			10			3			—			14
Net transfers in (out) of Level 3			—			—			—			—			—
Balance at December 31, 2013			3			291			89			47			430
Actual return on plan assets			—			9			15			—			24
Purchases, sales or other settlements			(1	)		2			1			1			3
Net transfers in (out) of Level 3			—			—			—			—			—
Balance at December 31, 2014		$	2		$	302		$	105		$	48		$	457
*	Fixed Income includes treasury and government issued, government related, mortgage‑backed and corporate securities.
The Corporation has budgeted contributions of approximately $55 million to its funded pension plans in 2015.
Estimated future benefit payments by the funded and unfunded pension plans and the postretirement medical plan, which reflect expected future service, are as follows (in millions):
2015		$	157
2016			112
2017			118
2018			121
2019			129
Years 2020 to 2024			694
The Corporation also contributes to several defined contribution plans for eligible employees. Employees may contribute a portion of their compensation to the plans and the Corporation matches a portion of the employee contributions. The Corporation recorded expense of $32 million in 2014, $41 million in 2013 and $40 million in 2012 for contributions to these plans.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	14. Income Taxes
	The provision (benefit) for income taxes from continuing operations consisted of:
			2014			2013			2012
			(In millions)
	United States
	Federal
	Current		$	(1	)	$	8		$	30
	Deferred			156			103			(435	)
	State			57			9			31
				212			120			(374	)
	Foreign
	Current			453			941			2,012
	Deferred			79			186			(224	)
				532			1,127			1,788
	Total			744			1,247			1,414
	Adjustment of deferred taxes for foreign income tax law changes*			—			(682	)		115
	Total provision for income taxes		$	744		$	565		$	1,529
	*	The reported amount for 2013 reflects $674 million for the effect of the Denmark hydrocarbon income tax law change to the Chapter 3A regime from the Chapter 3 regime in December 2013 and $8 million for the effect of a change in Norway’s hydrocarbon and base corporate income tax rates in December 2013. In 2012, the reported amount reflects the effect of the UK supplementary income tax rate change in July 2012.
	Income from continuing operations before income taxes consisted of the following:
			2014			2013			2012
			(In millions)
	United States (a)		$	676		$	580		$	(608	)
	Foreign			1,760			4,021			3,945
	Total income from continuing operations before income taxes		$	2,436		$	4,601		$	3,337
	(a)	Includes substantially all of the Corporation’s interest expense, corporate expense and the results of commodity hedging activities.
	The components of deferred tax liabilities and deferred tax assets at December 31 were as follows:
			2014			2013
			(In millions)
	Deferred tax liabilities
	Property, plant and equipment and investments		$	(5,361	)	$	(5,581	)
	Other			(269	)		(155	)
	Total deferred tax liabilities			(5,630	)		(5,736	)
	Deferred tax assets
	Net operating loss carryforwards			3,010			2,726
	Tax credit carryforwards			193			161
	Property, plant and equipment and investments			2,245			2,643
	Accrued compensation, deferred credits and other liabilities			449			982
	Asset retirement obligations			1,421			1,516
	Other			261			216
	Total deferred tax assets			7,579			8,244
	Valuation allowances			(1,416	)		(1,519	)
	Total deferred tax assets, net of valuation allowances			6,163			6,725
	Net deferred tax assets		$	533		$	989
	At December 31, 2014, the Corporation has recognized a gross deferred tax asset related to net operating loss carryforwards of $3,010 million before application of valuation allowances. The deferred tax asset is comprised of $2,131 million attributable to foreign net operating losses which begin to expire in 2029, $712 million attributable to U.S. federal operating losses which begin to expire in 2020 and $167 million attributable to losses in various U.S. states which begin to expire in 2015. The deferred tax asset attributable to foreign net operating losses, net of valuation allowances, is $1,504 million, substantially all of which relates to loss carryforwards in Denmark, Norway and Malaysia. At December 31, 2014, the Corporation has federal, state and foreign alternative minimum tax credit carryforwards of $109 million which can be carried forward indefinitely, and approximately $1 million of other business credit carryforwards. Foreign tax credit carryforwards, which begin to expire in 2016, total $83 million.
	In the Consolidated Balance Sheet, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:
			2014			2013
			(In millions)
	Other current assets		$	373		$	963
	Deferred income taxes (long-term asset)			2,169			2,319
	Accrued liabilities			—			(1	)
	Deferred income taxes (long-term liability)			(2,009	)		(2,292	)
	Net deferred tax assets		$	533		$	989
	A net deferred tax asset of $5 million relating to the energy trading joint venture, HETCO, is included in current assets associated with assets held for sale in the consolidated balance sheet at December 31, 2014.  A net deferred tax liability of $157 million, primarily relating to fixed asset basis differences and net operating losses of the Corporation’s subsidiaries in Thailand and Indonesia, is included in current liabilities associated with assets held for sale in the Consolidated Balance Sheet at December 31, 2013.
	The difference between the Corporation’s effective income tax rate from continuing operations and the U.S. statutory rate is reconciled below:
			2014			2013			2012
	U.S. statutory rate			35	%		35	%		35	%
	Effect of foreign operations*			1			6.9			12.5
	State income taxes, net of Federal income tax			1.5			0.1			0.6
	Change in enacted tax laws			—			(14.8	)		3.4
	Gains on asset sales, net			(8.3	)		(15.6	)		(5.4	)
	Other			1.3			0.7			(0.3	)
	Total			30.5	%		12.3	%		45.8	%
	*	The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the suspension of operations in Libya for a portion of 2013 and most of 2014.
	Below is a reconciliation of the gross beginning and ending amounts of unrecognized tax benefits:
		2014			2013
		(In millions)
Balance at January 1		$	570		$	523
Additions based on tax positions taken in the current year			42			161
Additions based on tax positions of prior years			70			2
Reductions based on tax positions of prior years			(76	)		(96	)
Reductions due to settlements with taxing authorities			(3	)		(19	)
Reductions due to lapses in statutes of limitation			—			(1	)
Balance at December 31		$	603		$	570
The December 31, 2014 balance of unrecognized tax benefits includes $528 million that, if recognized, would impact the Corporation’s effective income tax rate. Over the next 12 months, it is reasonably possible that the total amount of unrecognized tax benefits could decrease by up to $94 million due to settlements with taxing authorities or other resolutions, as well as lapses in statutes of limitation. The Corporation had accrued interest and penalties related to unrecognized tax benefits of $62 million and $52 million as of December 31, 2014 and 2013, respectively.
The Corporation has not recognized deferred income taxes on the portion of undistributed earnings of foreign subsidiaries expected to be indefinitely reinvested in foreign operations. The Corporation had undistributed earnings from foreign subsidiaries that it expects to be indefinitely reinvested in foreign operations of approximately $8.3 billion as of December 31, 2014.  The Corporation has not measured the unrecognized deferred tax liability related to these earnings because this determination is not practicable.
The Corporation and its subsidiaries file income tax returns in the U.S. and various foreign jurisdictions. The Corporation is no longer subject to examinations by income tax authorities in most jurisdictions for years prior to 2005.
Income taxes paid (net of refunds) in 2014, 2013 and 2012 amounted to $455 million, $1,353 million and $1,822 million, respectively.

Outstanding_and_Weighted_Avera

Outstanding and Weighted Average Common Shares	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Outstanding and Weighted Average Common Shares	15. Outstanding and Weighted Average Common Shares
	The following table provides the changes in the Corporation’s outstanding common shares:
			2014			2013			2012
			(In millions)
	Balance at January 1			325.3			341.5			340
	Activity related to restricted common stock awards, net			0.6			0.8			1.3
	Stock options exercised			3.3			2.3			0.2
	Shares repurchased*			(43.4	)		(19.3	)		—
	Balance at December 31			285.8			325.3			341.5
		*  See Note 16, Share Repurchase Plan in the Notes to the Consolidated Financial Statements.
	The following table presents the calculation of basic and diluted earnings per share:
			2014			2013			2012
			(In millions)
	Income from continuing operations, net of income taxes		$	1,692		$	4,036		$	1,808
	Less: Net income attributable to noncontrolling interests			—			176			18
	Net income from continuing operations attributable to Hess Corporation			1,692			3,860			1,790
	Income from discontinued operations, net of income taxes			682			1,186			255
	Less: Net income (loss) attributable to noncontrolling interests			57			(6	)		20
	Net income from discontinued operations attributable Hess Corporation			625			1,192			235
	Net income attributable to Hess Corporation		$	2,317		$	5,052		$	2,025
	Weighted average common shares outstanding:
	Basic			303.7			336.6			338.4
	Effect of dilutive securities
	Restricted common stock			1.5			1.4			1.1
	Stock options			1.8			1.7			0.8
	Performance share units			0.7			1.2			—
	Diluted			307.7			340.9			340.3
	Net income attributable to Hess Corporation per share:
	Basic:
	Continuing operations		$	5.57		$	11.47		$	5.29
	Discontinued operations			2.06			3.54			0.69
	Net income per share		$	7.63		$	15.01		$	5.98
	Diluted:
	Continuing operations		$	5.5		$	11.33		$	5.26
	Discontinued operations			2.03			3.49			0.69
	Net income per share		$	7.53		$	14.82		$	5.95
	The weighted average common shares used in the diluted earnings per share calculations exclude the effect of approximately 1.4 million, 4.4 million and 9.2 million out‑of‑the‑money stock options for 2014, 2013 and 2012, respectively. Based on the Corporation’s TSR, the diluted earnings per share calculations also exclude the effects of 414,175 PSUs for 2012.
	In 2014, cash dividends on common stock totaled $1.00 per share ($0.25 per quarter).  In 2013, cash dividends declared on common stock totaled $0.70 per share ($0.10 per share for the first two quarters and $0.25 per share commencing in the third quarter of 2013).  Cash dividends were $0.40 per share ($0.10 per quarter) in 2012.

Share_Repurchase_Plan

Share Repurchase Plan	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Share Repurchase Plan	16.  Share Repurchase Plan
	In March 2013, the Corporation announced a board authorized plan to repurchase up to $4.0 billion of outstanding common shares. In May 2014, the Corporation increased the repurchase program to $6.5 billion. For the year ended December 31, 2014, the Corporation purchased approximately 43.4 million shares for a total cost of approximately $3.7 billion, or an average cost of $85.83 per share including transaction fees. From August through December 31, 2013, the Corporation purchased approximately 19.3 million shares for a total cost of approximately $1.5 billion, or an average cost of $79.65 per share including transaction fees. As of December 31, 2014, the Corporation is authorized to purchase up to approximately $1.24 billion of additional common stock under its board approved plan.  Due to the current oil price environment, the Corporation plans to significantly moderate stock repurchases in 2015 compared with 2014.

Leased_Assets

Leased Assets	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Leased Assets Text Block	17. Leased Assets
	The Corporation and certain of its subsidiaries lease drilling rigs, tankers, office space and other assets for varying periods under contractual obligations accounted for as operating leases. Operating lease expenses for drilling rigs used to drill development wells and successful exploration wells are capitalized. At December 31, 2014, future minimum rental payments applicable to non‑cancelable operating leases with remaining terms of one year or more (other than oil and gas property leases) are as follows (in millions):
	2015	$	773
	2016		627
	2017		422
	2018		348
	2019		303
	Remaining years		345
	Total minimum lease payments		2,818
	Less: Income from subleases		36
	Net minimum lease payments	$	2,782
	Rental expense was as follows:
		2014		2013		2012
		(In millions)
	Total rental expense	$	248	$	355	$	375
	Less: Income from subleases		17		15		15
	Net rental expense	$	231	$	340	$	360

Guarantees_and_Contingencies

Guarantees and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments And Contingencies Disclosure [Abstract]
Guarantees and Contingencies	18.  Guarantees and Contingencies
	At December 31, 2014, the Corporation has $54 million in letters of credit for which it is contingently liable. In addition, the Corporation is subject to loss contingencies with respect to various lawsuits, claims and other proceedings, including environmental matters. A liability is recognized in the Corporation’s consolidated financial statements when it is probable that a loss has been incurred and the amount can be reasonably estimated. If the risk of loss is probable, but the amount cannot be reasonably estimated or the risk of loss is only reasonably possible, a liability is not accrued; however, the Corporation discloses the nature of those contingencies.
	In July 2004, HOVIC and HOVENSA, each received a letter from the Commissioner of the Virgin Islands Department of Planning and Natural Resources and Natural Resources Trustees, advising of the Trustee’s intention to bring suit against HOVIC and HOVENSA under the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA). The letter alleges that HOVIC and HOVENSA are potentially responsible for damages to natural resources arising from releases of hazardous substances from the HOVENSA refinery, which had been operated by HOVIC until October 1998. An action was filed on May 5, 2005 in the District Court of the Virgin Islands against HOVENSA, HOVIC and other companies that operated industrial facilities on the south shore of St. Croix asserting that the defendants are liable under CERCLA and territorial statutory and common law for damages to natural resources. In 2014 HOVIC, HOVENSA and the government of the U.S. Virgin Islands entered into a settlement agreement pursuant to which HOVENSA paid $3.5 million and agreed to pay the government of the U.S. Virgin Islands an additional $40 million no later than December 31, 2014.  HOVENSA was unable to make this additional payment because the U.S.Virgin Islands legislature did not approve a proposed operating agreement required to complete a proposed sale of HOVENSA, which would have provided funds to make the settlement payment. Under the terms of the settlement agreement, the U.S. Virgin Islands government was granted a first lien on HOVENSA’s assets to secure the settlement payment, and in January 2015 the government commenced a foreclosure action to enforce this lien.  HOVENSA intends to defend this action and may take other steps in response to the action, including the sale of assets and/or the commencement of bankruptcy proceedings. The Registrant does not believe that the resolution of this matter will have a material adverse effect on its financial condition.
	In February 2015, the Pension Benefit Guaranty Corporation (PBGC) issued a notice of determination to terminate the HOVENSA pension plan. HOVENSA had been in negotiations with the PBGC to make additional contributions to the plan with proceeds from a proposed sale of HOVENSA, which was not completed for the reasons described above. The Registrant does not believe that the resolution of this matter will have a material adverse effect on its financial condition.
	The Corporation, along with many companies engaged in refining and marketing of gasoline, has been a party to lawsuits and claims related to the use of methyl tertiary butyl ether (MTBE) in gasoline.  A series of similar lawsuits, many involving water utilities or governmental entities, were filed in jurisdictions across the U.S. against producers of MTBE and petroleum refiners who produced gasoline containing MTBE, including the Corporation.  The principal allegation in all cases was that gasoline containing MTBE is a defective product and that these parties are strictly liable in proportion to their share of the gasoline market for damage to groundwater resources and are required to take remedial action to ameliorate the alleged effects on the environment of releases of MTBE.  The majority of the cases asserted against the Corporation have been settled.  In March 2014, the Corporation agreed to settle claims against it arising out of an action brought by the State of New Jersey for approximately $35 million.   The settlement was approved by the trial judge and the Corporation paid the settlement amount in December 2014.  In June 2014, the Commonwealth of Pennsylvania and the State of Vermont each filed independent lawsuits alleging that the Corporation and all major oil companies with operations in each respective state, have damaged the groundwater in those states by introducing thereto gasoline with MTBE.  The Pennsylvania suit has been removed to Federal court and has been forwarded to the existing MTBE multidistrict litigation pending in the Southern District of New York. The suit filed in Vermont is proceeding there in a state court.  An action brought by the Commonwealth of Puerto Rico also remained unresolved at December 31, 2014. The Corporation has recorded reserves for its estimated liabilities for its unresolved MTBE lawsuits.
	The Corporation is subject to loss contingencies with respect to various claims, lawsuits and other proceedings. The Corporation cannot predict with certainty if, how or when such claims, lawsuits and proceedings will be resolved or what the eventual relief, if any, may be. Numerous issues may need to be resolved, including through lengthy discovery, conciliation and/or arbitration proceedings, or litigation before a loss or range of loss can be reasonably estimated. Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of such lawsuits, claims and proceedings is not expected to have a material adverse effect on the financial condition of the Corporation. However, the Corporation could incur judgments, enter into settlements or revise its opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on its results of operations in the period in which the amounts are accrued and its cash flows in the period in which the amounts are paid.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Information	19. Segment Information
	The Corporation has substantially completed its transition to a pure play E&P company.  The results of operations for its retail, energy marketing, terminal and refining businesses as well as the energy trading joint venture, HETCO, have been classified as discontinued operations.  The Corporation currently has one operating segment, Exploration and Production, and other unallocated costs reflected under Corporate, Interest and Other.  The following table presents operating segment financial data for continuing operations:
			Exploration		Corporate,			Total
			and		Interest
			Production		and Other
			(In millions)
	2014
	Operating revenues		$	10,737	$	—		$	10,737
	Net income (loss) from continuing operations attributable to Hess Corporation		$	2,098	$	(406	)	$	1,692
	Interest expense		$	—	$	323		$	323
	Depreciation, depletion and amortization			3,210		14			3,224
	Provision (benefit) for income taxes			996		(252	)		744
	Investments in affiliates			151		—			151
	Identifiable assets			36,512		908			37,420
	Capital expenditures			5,221		53			5,274
	2013
	Operating revenues		$	11,905	$	—		$	11,905
	Net Income (loss) from continuing operations attributable to Hess Corporation		$	4,303	$	(443	)	$	3,860
	Interest expense		$	—	$	406		$	406
	Depreciation, depletion and amortization			2,671		16			2,687
	Asset impairments			289		—			289
	Provision (benefit) for income taxes			831		(266	)		565
	Investments in affiliates			109		397			506
	Identifiable assets			37,863		1,352			39,215
	Capital expenditures			5,709		58			5,767
	2012
	Operating revenues		$	12,245	$	—		$	12,245
	Net income (loss) from continuing operations attributable to Hess Corporation		$	2,212	$	(422	)	$	1,790
	Interest expense		$	—	$	419		$	419
	Depreciation, depletion and amortization			2,853		13			2,866
	Asset impairments			582		—			582
	Provision (benefit) for income taxes			1,793		(264	)		1,529
	Investments in affiliates			75		198			273
	Identifiable assets			37,687		813			38,500
	Capital expenditures			7,676		6			7,682
	The following table presents financial information by major geographic area:
			United		Europe			Africa		Asia and		Corporate,			Total
			States							Other		Interest
										Countries		and Other
			(In millions)
	2014
	Operating revenues		$	6,270	$	1,557		$	2,002	$	908	$	—		$	10,737
	Net income (loss) from continuing operations attributable to Hess Corporation			656		226			545		671		(406	)		1,692
	Depreciation, depletion and amortization			1,751		683			487		289		14			3,224
	Provision (benefit) for income taxes			446		91			435		24		(252	)		744
	Identifiable assets			18,472		7,800			3,049		7,191		908			37,420
	Property, plant and equipment (net) (a)			15,595		6,339			2,235		3,232		116			27,517
	Capital expenditures			3,467		524			399		831		53			5,274
	2013
	Operating revenues		$	6,076	$	1,337		$	2,736	$	1,756	$	—		$	11,905
	Net income (loss) from continuing operations attributable to Hess Corporation			777		2,051			594		881		(443	)		3,860
	Depreciation, depletion and amortization			1,393		484			518		276		16			2,687
	Asset impairments			—		—			—		289		—			289
	Provision (benefit) for income taxes			495		(646	)		767		215		(266	)		565
	Identifiable assets			18,617		9,032			3,198		7,016		1,352			39,215
	Property, plant and equipment (net) (a)			14,873		7,475			2,310		2,899		193			27,750
	Capital expenditures			3,613		689			578		829		58			5,767
	2012
	Operating revenues		$	5,294	$	2,530		$	2,484	$	1,937	$	—		$	12,245
	Net income (loss) from continuing operations attributable to Hess Corporation			438		1,010			602		162		(422	)		1,790
	Depreciation, depletion and amortization			1,406		466			529		452		13			2,866
	Asset impairments			432		119			—		31		—			582
	Provision (benefit) for income taxes			267		376			905		245		(264	)		1,529
	Identifiable assets			16,403		8,957			3,811		8,516		813			38,500
Property, plant and equipment (net) (a)			12,893		8,172			2,516		3,875		86			27,542
Capital expenditures			4,620		1,330			733		993		6			7,682
(a)	Of the total Europe, Property, plant and equipment (net), Norway represented $5,246 million, $6,348 million and $6,426 million in 2014, 2013, and 2012, respectively.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	20. Related Party Transactions
	The following table presents the Corporation’s related party transactions:
			2014		2013			2012
			(In millions)
	Purchases:
	HOVENSA (a)		$	—	$	—		$	145
	Bayonne Energy Center LLC (b)			—		38			20
	Sales:
	WilcoHess (c)			211		2,828			3,058
	HOVENSA			31		90			191
	(a)	The Corporation ceased purchasing refined products from HOVENSA following the closure of HOVENSA’s refinery in January 2012.
	(b)	Represents purchases of electricity from this 50% owned joint venture under a tolling agreement.
	(c)	The Corporation acquired its partners’ 56% interest in WilcoHess in January 2014.
	The following table presents the Corporation’s related party accounts receivable (payable) at December 31:
			2014		2013
			(In millions)
	WilcoHess		$	—	$	114
	Bayonne Energy Center LLC			—		(4	)

Financial_Risk_Management_and_

Financial Risk Management and Trading Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Financial Risk Management and Trading Activities	21. Financial 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 and natural gas as well as changes in interest rates and foreign currency values. In the disclosures that follow, corporate risk management activities refer to the mitigation of these risks through hedging activities. The Corporation is also exposed to commodity price risks primarily related to crude oil, natural gas, refined petroleum products and electricity, as well as foreign currency values from a 50% voting interest in a consolidated energy trading joint venture. The energy trading joint venture was sold in February 2015.
	In conjunction with the sale of the energy marketing business in the fourth quarter of 2013, certain derivative contracts, including new transactions following the closing date, (the “delayed transfer derivative contracts”) were not transferred to the acquirer, Direct Energy, a North American subsidiary of Centrica plc (Centrica), as required customer or regulatory consents had not been obtained. However, the agreement entered into between Hess and Direct Energy on the closing date transferred all economic risks and rewards of the energy marketing business, including the ownership of the delayed transfer derivative contracts, to Direct Energy. The transfer of these remaining contracts was completed during 2014.
	The Corporation maintains a control environment for all of its financial risk management and trading activities 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 and commodities. Risk limits are monitored and reported on a daily basis to business units and senior management. The Corporation’s financial risk management department also performs independent price verifications (IPV’s) of sources of fair values and validations of valuation models. 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 financial 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.
	The 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 beginning 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.
	Corporate Financial Risk Management Activities: Financial risk management activities include transactions designed to reduce risk in the selling prices of crude oil 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 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, primarily the British Pound and Danish Krone. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.
	The gross volumes of the financial risk management derivative contracts outstanding at December 31, were as follows:
			2014			2013
	Commodity, primarily crude oil (millions of barrels)			—			9
	Foreign exchange (millions of USD*)		$	1,189		$	220
	Interest rate swaps (millions of USD)		$	1,300		$	865
	*Denominated in U.S. dollars (USD).
	Crude oil price hedging contracts increased E&P Sales and other operating revenues by $193 million ($121 million after income taxes) and $39 million ($25 million after income taxes) in 2014 and 2013, respectively, and reduced E&P Sales and other operating revenues by $688 million ($431 million after income taxes) in 2012.  The amount of ineffectiveness from crude oil hedges that was recognized immediately in Sales and other operating revenues was immaterial in 2014 and 2013, and a loss of $9 million in 2012.  At December 31, 2014, the Corporation has no after‑tax deferred gains in Accumulated other comprehensive income (loss) related to Brent crude oil and West Texas Intermediate (WTI) crude oil hedges.
	At December 31, 2014 and 2013, the Corporation had interest rate swaps with gross notional amounts of $1,300 million and $865 million, respectively, 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. For the years ended December 31, 2014 and 2013, the Corporation recorded an increase of $1 million and a decrease of $35 million (excluding accrued interest) 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 in Corporate Risk Management activities and not designated as hedges amounted to the following:
			2014			2013			2012
			(In millions)
	Commodity		$	—		$	—		$	1
	Foreign exchange			117			(39	)		43
	Total		$	117		$	(39	)	$	44
	Trading Activities: The energy trading joint venture generated earnings through various strategies primarily using energy-related commodities, securities and derivatives. The information that follows represents 100% of the energy trading joint venture as well as the Corporation’s proprietary trading activities, which ceased in 2013.
	The gross volumes of derivative contracts outstanding related to trading activities at December 31, were as follows:
			2014			2013
	Commodity
	Crude oil and refined petroleum products (millions of barrels)			1,396			1,815
	Natural gas (millions of mcf)			2,224			2,735
	Electricity (millions of megawatt hours)			1			1
	Foreign exchange (millions of USD)		$	77		$	52
	Interest rate (millions of USD)		$	29		$	—
	Equity securities (millions of shares)			5			11
	Pre‑tax unrealized and realized gains (losses) recorded in the Statement of Consolidated Income from trading activities amounted to the following:
			2014			2013			2012
			(In millions)
	Commodity		$	168		$	78		$	104
	Foreign exchange			2			—			3
	Other			32			1			10
	Total *		$	202		$	79		$	117
	*	The unrealized pre‑tax gains and losses included in earnings were reflected in Income from discontinued operations in the Statement of Consolidated Income.
	Fair Value Measurements: The Corporation generally enters into master netting arrangements to mitigate legal and counterparty credit risk. Master netting arrangements are generally accepted overarching master contracts that govern all individual transactions with the same counterparty entity as a single legally enforceable agreement. The U.S. Bankruptcy Code provides for the enforcement of certain termination and netting rights under certain types of contracts upon the bankruptcy filing of a counterparty, commonly known as the “safe harbor” provisions. If a master netting arrangement provides for termination and netting upon the counterparty’s bankruptcy, these rights are generally enforceable with respect to “safe harbor” transactions. If these arrangements provide the right of offset and the Corporation’s intent and practice is to offset amounts in the case of such a termination, the Corporation’s policy is to record the fair value of derivative assets and liabilities on a net basis.
	In the normal course of business the Corporation relies on legal and credit risk mitigation clauses providing for adequate credit assurance as well as close‑out netting, including two‑party netting and single counterparty multilateral netting. As applied to the Corporation, “two‑party netting” is the right to net amounts owing under safe harbor transactions between a single defaulting counterparty entity and a single Hess entity, and “single counterparty multilateral netting” is the right to net amounts owing under safe harbor transactions among a single defaulting counterparty entity and multiple Hess entities. The Corporation is reasonably assured that these netting rights would be upheld in a bankruptcy proceeding in the U.S. in which the defaulting counterparty is a debtor under the U.S. Bankruptcy Code.
	The following table provides information about the effect of netting arrangements on the presentation of the Corporation’s physical and financial derivative assets and (liabilities) that are measured at fair value, with the effect of single counterparty multilateral netting being included in column (v):
						Gross Amounts Offset in the
						Consolidated Balance Sheet
			Gross Amounts			Physical			Cash Collateral (a)			Net Amounts			Gross Amounts			Net Amounts
						Derivative and						Presented in the			Not Offset in the
						Financial						Consolidated			Consolidated
						Instruments						Balance Sheet			Balance Sheet
			(i)			(ii)			(iii)			(iv)=)+(ii)+(iii)			(v)			(vi)=v)+(v)
			(In millions)
	December 31, 2014
	Assets
	Derivative contracts
	Commodity		$	7,465		$	(6,664	)	$	(36	)	$	765		$	(3	)	$	762
	Interest rate and other			76			(7	)		(1	)		68			(1	)		67
	Counterparty netting			—			(63	)		—			(63	)		—			(63	)
	Total derivative contracts		$	7,541		$	(6,734	)	$	(37	)	$	770		$	(4	)	$	766
	Liabilities
	Derivative contracts
	Commodity		$	(7,871	)	$	6,664		$	299		$	(908	)	$	3		$	(905	)
	Interest rate and other			(13	)		7			3			(3	)		1			(2	)
	Counterparty netting			—			63			—			63			—			63
	Total derivative contracts		$	(7,884	)	$	6,734		$	302		$	(848	)	$	4		$	(844	)
December 31, 2013 (b)
Assets
Derivative contracts
Commodity		$	3,086		$	(1,867	)	$	(79	)	$	1,140		$	(41	)	$	1,099
Interest rate and other			51			(10	)		—			41			(3	)		38
Counterparty netting			—			(206	)		—			(206	)		—			(206	)
Total derivative contracts		$	3,137		$	(2,083	)	$	(79	)	$	975		$	(44	)	$	931
Liabilities
Derivative contracts
Commodity		$	(3,212	)	$	1,867		$	168		$	(1,177	)	$	41		$	(1,136	)
Other			(12	)		10			—			(2	)		3			1
Counterparty netting			—			206			—			206			—			206
Total derivative contracts		$	(3,224	)	$	2,083		$	168		$	(973	)	$	44		$	(929	)
(a)	All cash collateral was offset in the Consolidated Balance Sheet.
(b)	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
The net assets and liabilities that were offset in the Consolidated Balance Sheet as reflected in column (iv) of the table above were primarily included in Accounts receivable—Trade and Accounts payable, respectively. Included in these net amounts were the assets and liabilities related to the Corporation’s discontinued operations of approximately $701 million and $845 million, respectively, as of December 31, 2014, and $612 million and $620 million, respectively, as of December 31, 2013.
The table below reflects the gross and net fair values of the risk management and trading derivative instruments and, at December 31, 2013 also includes energy marketing risk management derivative instruments:
		Accounts			Accounts
		Receivable			Payable
		(In millions)
December 31, 2014
Derivative contracts designated as hedging instruments
Commodity		$	—		$	—
Interest rate and other			39			(2	)
Total derivative contracts designated as hedging instruments			39			(2	)
Derivative contracts not designated as hedging instruments (a)
Commodity			7,465			(7,871	)
Foreign exchange			31			—
Other			6			(11	)
Total derivative contracts not designated as hedging instruments			7,502			(7,882	)
Gross fair value of derivative contracts			7,541			(7,884	)
Master netting arrangements			(6,734	)		6,734
Cash collateral (received) posted			(37	)		302
Net fair value of derivative contracts		$	770		$	(848	)
December 31, 2013 (b)
Derivative contracts designated as hedging instruments
Commodity		$	11		$	(3	)
Interest rate and other			36			(1	)
Total derivative contracts designated as hedging instruments			47			(4	)
Derivative contracts not designated as hedging instruments (a)
Commodity			3,075			(3,209	)
Foreign exchange			2			(3	)
Other			13			(8	)
Total derivative contracts not designated as hedging instruments			3,090			(3,220	)
Gross fair value of derivative contracts			3,137			(3,224	)
Master netting arrangements			(2,083	)		2,083
Cash collateral (received) posted			(79	)		168
Net fair value of derivative contracts		$	975		$	(973	)
(a)	Includes trading derivatives and derivatives used for risk management
(b)	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business
Fair Value Measurements:
The following table provides the Corporation’s net physical derivative and financial assets and (liabilities) that are measured at fair value based on this hierarchy:
		Level 1			Level 2			Level 3			Counterparty			Collateral			Balance
											netting
		(In millions)
December 31, 2014
Assets
Derivative contracts
Commodity		$	755		$	390		$	114		$	(458	)	$	(36	)	$	765
Interest rate and other			(1	)		70			—			—			(1	)		68
Collateral and counterparty netting			(43	)		(20	)		—			—			—			(63	)
Total derivative contracts			711			440			114			(458	)		(37	)		770
Other assets measured at fair value on a recurring basis			27			—			—			—			—			27
Total assets measured at fair value on a recurring basis		$	738		$	440		$	114		$	(458	)	$	(37	)	$	797
Liabilities
Derivative contracts
Commodity		$	(338	)	$	(1,265	)	$	(62	)	$	458		$	299		$	(908	)
Other			(3	)		(1	)		(2	)		—			3			(3	)
Collateral and counterparty netting			43			20			—			—			—			63
Total derivative contracts			(298	)		(1,246	)		(64	)		458			302			(848	)
Other liabilities measured at fair value on a recurring basis			(40	)		—			—			—			—			(40	)
Total liabilities measured at fair value on a recurring basis		$	(338	)	$	(1,246	)	$	(64	)	$	458		$	302		$	(888	)
Other fair value measurement disclosures     Long-term debt (a)		$	—		$	(7,003	)	$	—		$	—		$	—		$	(7,003	)
December 31, 2013 (b)
Assets
Derivative contracts
Commodity		$	254		$	579		$	494		$	(108	)	$	(79	)	$	1,140
Interest rate and other			2			37			3			(1	)		—			41
Collateral and counterparty netting			(15	)		(191	)		—			—			—			(206	)
Total derivative contracts			241			425			497			(109	)		(79	)		975
Other assets measured at fair value on a recurring basis			—			—			—			—			—			—
Total assets measured at fair value on a recurring basis		$	241		$	425		$	497		$	(109	)	$	(79	)	$	975
Liabilities
Derivative contracts
Commodity		$	(97	)	$	(1,071	)	$	(285	)	$	108		$	168		$	(1,177	)
Other			—			(3	)		—			1			—			(2	)
Collateral and counterparty netting			15			191			—			—			—			206
Total derivative contracts			(82	)		(883	)		(285	)		109			168			(973	)
Other liabilities measured at fair value on a recurring basis			(31	)		—			—			—			—			(31	)
Total liabilities measured at fair value on a recurring basis		$	(113	)	$	(883	)	$	(285	)	$	109		$	168		$	(1,004	)
Other fair value measurement disclosures     Long-term debt (a)		$	—		$	(6,641	)	$	—		$	—		$	—		$	(6,641	)
(a)	Long-term debt, including current maturities, had a carrying value of $5,987 million and $5,798 million at December 31, 2014 and 2013, respectively.
(b)	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
In addition to the financial assets and (liabilities) disclosed in the tables above, the Corporation had other short‑term financial instruments, primarily cash equivalents and accounts receivable and payable, for which the carrying value approximated their fair value at December 31, 2014 and 2013.
The following table provides total net transfers into and out of each level of the fair value hierarchy:
		2014			2013
		(In millions)
Transfers into Level 1		$	25		$	3
Transfers out of Level 1			(47	)		76
		$	(22	)	$	79
Transfers into Level 2		$	25		$	(113	)
Transfers out of Level 2			(128	)		88
		$	(103	)	$	(25	)
Transfers into Level 3		$	105		$	(85	)
Transfers out of Level 3			20			31
		$	125		$	(54	)
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 following table provides changes in physical derivatives and financial assets and (liabilities) primarily related to commodities that are measured at fair value based on Level 3 inputs:
		2014			2013
		(In millions)
Balance at January 1		$	212		$	141
Unrealized pre-tax gains (losses)
Included in earnings (a)			(298	)		175
Purchases (b)			31			45
Sales (b)			(24	)		(34	)
Settlements (c)			4			(61	)
Transfers into Level 3			105			(85	)
Transfers out of Level 3			20			31
Balance at December 31		$	50		$	212
(a)	The unrealized pre‑tax gains and losses included in earnings were reflected in Income from discontinued operations in the Statement of Consolidated Income.
(b)	Purchases and sales primarily represent option premiums paid or received, respectively, during the reporting period and were reflected in Income from discontinued operations in the Statement of Consolidated Income.
(c)	Settlements represent realized gains (losses) on derivatives settled during the reporting period and were reflected in Income from discontinued operations in the Statement of Consolidated Income.
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 in the table below represent full contract prices. Significant changes in any of the inputs, independently or correlated, may result in a different fair value.
		Unit of			Range /
		Measurement			Weighted Average
December 31, 2014
Assets
Commodity contracts with a fair value of $114 million
Contract prices
Crude oil and refined petroleum products			$ / bbl (a)		$	36.27 - 122.66 / 65.63
Electricity			$ / MWH (b)		$	38.80 - 71.69 / 57.22
Basis prices
Natural gas			$ / MMBTU (c)		$	(0.61) - 13.50 / 6.19
Contract volatilities
Crude oil and refined petroleum products			%			32.00 - 45.00 / 43.00
Natural gas			%			19.00 - 53.00 / 40.00
Liabilities
Commodity contracts with a fair value of $62 million
Contract prices
Crude oil and refined petroleum products			$ / bbl (a)		$	36.27 - 85.40 / 69.54
Basis prices
Natural gas			$ / MMBTU (c)		$	2.84 - 4.45 / 2.94
Contract volatilities
Crude oil and refined petroleum products			%			32.00 - 45.00 / 41.00
Natural gas			%			23.00 - 53.00 / 41.00
		Unit of			Range /
		Measurement			Weighted Average
December 31, 2013 (b)
Assets
Commodity contracts with a fair value of $494 million
Contract prices
Crude oil and refined petroleum products			$ / bbl (a)		$	78.45 - 228.86 / 118.68
Electricity			$ / MWH (b)		$	19.52 -165.75 / 45.76
Basis prices
Natural gas			$ / MMBTU (c)		$	(4.99) - 18.10 / 0.23
Contract volatilities
Crude oil and refined petroleum products			%			16.00 - 18.00 / 17.00
Natural gas			%			17.00 - 35.00 / 22.00
Electricity			%			16.00 - 36.00 / 23.00
Liabilities
Commodity contracts with a fair value of $285 million
Contract prices
Crude oil and refined petroleum products			$ / bbl (a)		$	57.45 - 183.89 / 122.54
Electricity			$ / MWH (b)		$	26.48 - 155.33 / 43.12
Basis prices
Natural gas			$ / MMBTU (c)		$	(1.90) - 18.00 / (0.62)
Contract volatilities
Crude oil and refined petroleum products			%			16.00 - 17.00 / 17.00
Natural gas			%			34.00 - 35.00 / 35.00
Electricity			%			16.00 – 36.00 / 22.00
(a)	Price per barrel.
(b)	Price per megawatt hour.
(c)	Price per million British thermal unit
(d	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
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. As of December 31, 2014, the Corporation’s net Accounts receivable—Trade related to continuing operations were concentrated with the following counterparty industry segments: Integrated Oil Companies — 23%, Financial Institutions — 22%, Government Entities —18%, Refiners — 14%, and Trading Companies — 13%. As of December 31, 2013, the Corporation’s net Accounts receivable —Trade, which included the receivables for the downstream businesses, were concentrated as follows: Integrated Oil Companies —  45%, Refiners — 18%, Financial Institutions — 14% Government Entities — 8%, and Trading Companies — 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 December 31, 2014 and December 31, 2013, the Corporation held cash from counterparties of $37 million and $79 million, respectively. The Corporation posted cash to counterparties at December 31, 2014 and December 31, 2013, of $302 million and $168 million, respectively.
The Corporation had outstanding letters of credit totaling $397 million and $410 million at December 31, 2014 and December 31, 2013, respectively, primarily issued to satisfy margin requirements (approximately $240 million and $302 million related to discontinued operations at December 31, 2014 and December 31, 2013, respectively). 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 December 31, 2014 and 2013, the net liability related to both realized and unrealized derivative contracts with contingent collateral provisions was $130 million and approximately $281 million, respectively. As of December 31, 2014, the cash collateral posted on those derivatives was $17 million compared to $31 million at December 31, 2013. At December 31, 2014 and 2013, all three major credit rating agencies that rate the Corporation’s debt had assigned an investment grade rating. If one of the three agencies were to downgrade the Corporation’s rating below investment grade, the Corporation would be required to post additional collateral of approximately $55 million at December 31, 2014 and approximately $134 million at December 31, 2013.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	22. Subsequent Events
	In January 2015, the Corporation entered into a new $4 billion syndicated revolving credit facility that matures in January 2020. The new facility, which replaced the $4 billion facility that was scheduled to mature in April 2016, can be used for borrowings and letters of credit. Borrowings on the facility bear interest at 1.075% above the London Interbank Offered Rate. A facility fee of 0.175% per annum is also payable on the amount of the facility. The interest rate and facility fee are subject to adjustment if the Corporation's credit rating changes. The restrictions on the amount of total borrowings and secured debt are substantially similar to the previous facility.
	In February 2015, the Corporation sold its interest in the energy trading joint venture, HETCO, which was renamed Hartree Partners, LP.  Pursuant to the terms of the sale, Hartree is permitted to continue to utilize the Corporation’s guarantees issued in favor of Hartree's existing counterparties until November 12, 2015, provided that new trades are for a period of one year or less, comply with certain credit requirements, and net exposures remain within VAR limits previously applied by the Corporation.  The Corporation has the right to seek reimbursement from Hartree and a separate Hartree credit support facility upon any counterparty draw on the applicable guarantee from the Corporation.

Valuation_and_Qualifying_Accou

Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2014
Valuation And Qualifying Accounts [Abstract]
Valuation and Qualifying Accounts	Schedule II
	HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
	VALUATION AND QUALIFYING ACCOUNTS
	For the Years Ended December 31, 2014, 2013 and 2012
						Additions
	Description	Balance		Charged to			Charged to			Deductions		Balance
		January 1		Costs and			Other			from Reserves		December 31
				Expenses			Accounts
			(In millions)
	2014
	Losses on receivables	$	27	$	—		$	—		$	14	$	13
	Deferred income tax valuation	$	1,519	$	142		$	(1	)	$	244	$	1,416
	2013
	Losses on receivables	$	34	$	10		$	—		$	17	$	27
	Deferred income tax valuation	$	1,282	$	383		$	(17	)	$	129	$	1,519
	2012
	Losses on receivables	$	55	$	—		$	—		$	21	$	34
	Deferred income tax valuation	$	1,071	$	248		$	—		$	37	$	1,282

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Principles of Consolidation and Basis of Presentation	Principles of Consolidation and Basis of Presentation:  The consolidated financial statements include the accounts of Hess Corporation and entities in which the Corporation owns more than a 50% voting interest or entities that the Corporation controls. The Corporation consolidates the energy trading joint venture in which it owns a 50% voting interest and over which it exercises control. The Corporation’s undivided interests in unincorporated oil and gas exploration and production ventures are proportionately consolidated. Investments in affiliated companies, 20% to 50% owned and where the Corporation has the ability to influence the operating or financial decisions of the affiliate, are accounted for using the equity method.
	The prior years’ financial information has been recast to reflect consolidated results of operations, cash flows and other information of the Corporation’s divested consolidated downstream businesses, the Port Reading refining facility, and HETCO as discontinued operations. See also Note 2, Discontinued Operations in the Notes to the Consolidated Financial Statements.  Certain other information in the financial statements and notes has been reclassified to conform to the current period presentation.
Estimates and Assumptions	Estimates and Assumptions:  In preparing financial statements in conformity with U.S. generally accepted accounting principles (GAAP), management makes estimates and assumptions that affect the reported amounts of assets and liabilities in the Consolidated Balance Sheet and revenues and expenses in the Statement of Consolidated Income. Actual results could differ from those estimates. Estimates made by management include oil and gas reserves, asset and other valuations, depreciable lives, pension liabilities, legal and environmental obligations, asset retirement obligations and income taxes.
Revenue Recognition	Revenue Recognition:  The Corporation recognizes revenues from the sale of crude oil, natural gas liquids, and natural gas, when title passes to the customer. The Corporation recognizes revenues from the production of natural gas properties based on sales to customers. Differences between E&P natural gas volumes sold and the Corporation’s entitlement share of natural gas production are not material. Sales of refined petroleum products and other merchandise from divested downstream operations were also recognized when title passed to customers.
	In its E&P activities, the Corporation engages in crude oil purchase and sale transactions with the same counterparty that are entered into in contemplation of one another for the primary purpose of changing location or quality. These arrangements are reported net in Sales and other operating revenues in the Statement of Consolidated Income.
Exploration and Development Costs	Exploration and Development Costs:  E&P activities are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Annual lease rentals, exploration expenses and exploratory dry hole costs are expensed as incurred. Costs of drilling and equipping productive wells, including development dry holes, and related production facilities are capitalized. In production operations, costs of injected CO2 for tertiary recovery are expensed as incurred.
	The costs of exploratory wells that find oil and gas reserves are capitalized pending determination of whether proved reserves have been found. Exploratory drilling costs remain capitalized after drilling is completed if (1) the well has found a sufficient quantity of reserves to justify completion as a producing well and (2) sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If either of those criteria is not met, or if there is substantial doubt about the economic or operational viability of a project, the capitalized well costs are charged to expense. Indicators of sufficient progress in assessing reserves and the economic and operating viability of a project include commitment of project personnel, active negotiations for sales contracts with customers, negotiations with governments, operators and contractors, firm plans for additional drilling and other factors.
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization:  The Corporation records depletion expense for acquisition costs of proved properties using the units of production method over proved oil and gas reserves. Depreciation and depletion expense for oil and gas production equipment and wells is calculated using the units of production method over proved developed oil and gas reserves. Provisions for impairment of undeveloped oil and gas leases are based on periodic evaluations and other factors. Depreciation of all other plant and equipment is determined on the straight-line method based on estimated useful lives.
Capitalized Interest	Capitalized Interest:  Interest from external borrowings is capitalized on material projects using the weighted average cost of outstanding borrowings until the project is substantially complete and ready for its intended use, which for oil and gas assets is at first production from the field. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying assets.
Impairment of Long-lived Assets	Impairment of Long‑lived Assets:  The Corporation reviews long‑lived assets, including oil and gas fields, for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recovered.    If the carrying amounts of the long-lived assets are not expected to be recovered by estimated undiscounted future net cash flows, the assets are impaired and an impairment loss is recorded.  The amount of impairment is determined based on the estimated fair value of the assets generally determined by discounting anticipated future net cash flows, an income valuation approach, or by a market‑based valuation approach, which are Level 3 fair value measurements.  In the case of oil and gas fields, the present value of future net cash flows is based on management’s best estimate of future prices, which is determined with reference to recent historical prices and published forward prices, applied to projected production volumes and discounted at a risk-adjusted rate.  The projected production volumes represent reserves, including probable reserves, expected to be produced based on a projected amount of capital expenditures.  The production volumes, prices and timing of production are consistent with internal projections and other externally reported information.  Oil and gas prices used for determining asset impairments will generally differ from those used in the standardized measure of discounted future net cash flows, since the standardized measure requires the use of historical twelve month average prices.  As a result of the significant decline in crude oil prices in the fourth quarter of 2014, the Corporation tested its oil and gas properties for impairment and determined no impairment existed at December 31, 2014.
Impairment of Goodwill	Impairment of Goodwill:  The Corporation’s goodwill is tested for impairment annually on October 1st or when events or circumstances indicate that the carrying amount of the goodwill may not be recoverable based on a two-step process.  The goodwill test is conducted at a reporting unit level, which is defined in accounting standards as an operating segment or one level below an operating segment.  Following a reorganization of its management structure in 2013, the Corporation concluded that within its E&P segment it has two reporting units, offshore and onshore.  In step one of the impairment test, the fair value of a reporting unit is compared with its carrying amount, including goodwill.  If the fair value of the reporting unit exceeds its carrying value, goodwill is not impaired.  If the carrying value of the reporting unit exceeds its fair value, the Corporation performs step two to determine possible impairment by comparing the implied fair value of goodwill with the carrying amount.  If the implied fair value of goodwill is less than its carrying amount, an impairment loss would be recorded.   The Corporation performed a separate goodwill impairment test at December 31, 2014, and determined no impairment existed.
Cash and Cash Equivalents	Cash and Cash Equivalents:  Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have maturities of three months or less when acquired.
Inventories	Inventories:  Inventories are valued at the lower of cost or market. Cost is generally determined using average actual costs.  At December 31, 2013, refined petroleum product inventories associated with the now divested downstream businesses were valued at cost, using principally the last‑in, first‑out (LIFO) inventory method.
Income Taxes	Income Taxes:  Deferred income taxes are determined using the liability method.  The Corporation has net operating loss carryforwards or credit carryforwards in multiple jurisdictions and has recorded deferred tax assets for those losses and credits.  Additionally, the Corporation has deferred tax assets due to temporary differences between the book basis and tax basis of certain assets and liabilities.  Regular assessments are made as to the likelihood of those deferred tax assets being realized.  If it is more likely than not that some or all of the deferred tax assets will not be realized, a valuation allowance is recorded to reduce the deferred tax assets to the amount that is expected to be realized.  In evaluating the realizability of deferred tax assets, the Corporation considers the reversal of temporary differences, the expected utilization of net operating losses and credit carryforwards during available carryforward periods, the availability of tax planning strategies, the existence of appreciated assets and estimates of future taxable income and other factors.  In addition, the Corporation recognizes the financial statement effect of a tax position only when management believes that it is more likely than not, that based on the technical merits, the position will be sustained upon examination.  The Corporation does not provide for deferred U.S. income taxes for that portion of undistributed earnings of foreign subsidiaries that are indefinitely reinvested in foreign operations.  The Corporation classifies interest and penalties associated with uncertain tax positions as income tax expense.
Asset Retirement Obligations	Asset Retirement Obligations:  The Corporation has material legal obligations to remove and dismantle long‑lived assets and to restore land or seabed at certain exploration and production locations. The Corporation recognizes a liability for the fair value of legally required asset retirement obligations associated with long‑lived assets in the period in which the retirement obligations are incurred. In addition, the fair value of any legally required conditional asset retirement obligations is recorded if the liability can be reasonably estimated. The Corporation capitalizes the associated asset retirement costs as part of the carrying amount of the long‑lived assets.
Retirement Plans	Retirement Plans:  The Corporation recognizes the funded status of defined benefit postretirement plans in the Consolidated Balance Sheet. The funded status is measured as the difference between the fair value of plan assets and the projected benefit obligation. The Corporation recognizes the net changes in the funded status of these plans in the year in which such changes occur. Prior service costs and actuarial gains and losses in excess of 10% of the greater of the benefit obligation or the market value of assets are amortized over the average remaining service period of active employees.
Derivatives	Derivatives:  The Corporation utilizes derivative instruments for both financial risk management and trading activities. In risk management activities, the Corporation may use futures, forwards, options and swaps, individually or in combination, to mitigate its exposure to fluctuations in prices of crude oil, natural gas, as well as changes in interest and foreign currency exchange rates. The Corporation, through a consolidated joint venture which is classified as held-for-sale at December 31, 2014, trades energy‑related commodities and derivatives including futures, forwards, options and swaps based on expectations of future market conditions.
	All derivative instruments are recorded at fair value in the Corporation’s Consolidated Balance Sheet. The Corporation’s policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized currently in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges) or hedges of firm commitments (fair value hedges). The effective portion of changes in fair value of derivatives that are designated as cash flow hedges is recorded as a component of other comprehensive income (loss) while the ineffective portion of the changes in fair value is recorded currently in earnings. Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings. Changes in fair value of derivatives designated as fair value hedges are recognized currently in earnings. The change in fair value of the related hedged commitment is recorded as an adjustment to its carrying amount and recognized currently in earnings.
Fair Value Measurements	Fair value measurements:  The Corporation uses various valuation approaches in determining fair value for financial instruments, including the market and income approaches.  The Corporation’s fair value measurements also include non-performance risk and time value of money considerations.  Counterparty credit is considered for receivable balances, and the Corporation’s credit is considered for accrued liabilities.  The Corporation also records certain nonfinancial assets and liabilities at fair value when required by GAAP. These fair value measurements are recorded in connection with business combinations, qualifying nonmonetary exchanges, the initial recognition of asset retirement obligations and any impairment of long‑lived assets, equity method investments or goodwill.  The Corporation determines fair value in accordance with the fair value measurements accounting standard which established a hierarchy for the inputs used to measure fair value based on the source of the 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 is based on the lowest significant input level within this fair value hierarchy.
	Details on the methods and assumptions used to determine the fair values are as follows:
	Fair value measurements based on Level 1 inputs:  Measurements that are most observable are based on quoted prices of identical instruments obtained from the principal markets in which they are traded. Closing prices are both readily available and representative of fair value. Market transactions occur with sufficient frequency and volume to assure liquidity.
	Fair value measurements based on Level 2 inputs:  Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2. Measurements based on Level 2 inputs include over-the-counter derivative instruments that are priced on an exchange traded curve, but have contractual terms that are not identical to exchange traded contracts.
	Fair value measurements based on Level 3 inputs:  Measurements that are least observable are estimated from related market data, determined from sources with little or no market activity for comparable contracts or are positions with longer durations. Fair values determined using discounted cash flows and other unobservable data are also classified as Level 3.
Share-based Compensation	Share-based Compensation:  The fair value of all share‑based compensation is recognized as expense on a straight‑line basis over the full vesting period of the awards. The Corporation estimates the fair value of employee stock options at the date of grant using a Black‑Scholes valuation model, performance share units using a Monte Carlo simulation model, and restricted stock based on the market value of the underlying shares at the date of grant.
Foreign Currency Translation	Foreign Currency Translation:  The U.S. Dollar is the functional currency (primary currency in which business is conducted) for most foreign operations. Adjustments resulting from translating monetary assets and liabilities that are denominated in a currency other than the functional currency are recorded in Other, net in the Statement of Consolidated Income. For operations that do not use the U.S. Dollar as the functional currency, primarily those in Norway where the Norwegian Krone is used, adjustments resulting from translating foreign currency assets and liabilities into U.S. Dollars are recorded in the Consolidated Balance Sheet in a separate component of equity titled Accumulated other comprehensive income (loss).
Maintenance and Repairs	Maintenance and Repairs:  Maintenance and repairs are expensed as incurred. Capital improvements are recorded as additions in Property, plant and equipment.
Environmental Expenditures	Environmental Expenditures:  The Corporation accrues and expenses the undiscounted environmental costs necessary to remediate existing conditions related to past operations when the future costs are probable and reasonably estimable. At year‑end 2014, the Corporation’s reserve for estimated remediation liabilities was approximately $80 million and was included within accrued liabilities.  Environmental expenditures that increase the life or efficiency of property or reduce or prevent future adverse impacts to the environment are capitalized.
New Accounting Pronouncements
	New Accounting Pronouncements:  In April 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The ASU amends the criteria for reporting discontinued operations to include only disposals representing a strategic shift in operations. The ASU also requires expanded disclosures regarding the assets, liabilities, income, and expenses of discontinued operations. This ASU is effective for the Corporation in the first quarter of 2015 and early adoption is permitted. The Corporation did not elect early adoption of this ASU and does not expect adoption to have a significant impact on its consolidated financial statements.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, as a new Accounting Standards Codification (ASC) Topic ASC 606. This ASU is effective for the Corporation beginning in the first quarter of 2017 and early adoption is not permitted. The Corporation is currently assessing the impact of the ASU on its consolidated financial statements.

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Discontinued Operations And Disposal Groups [Abstract]
Summary of Sales and Other Operating Revenues and Income from Discontinued Operations	Sales and other operating revenues and Income from discontinued operations were as follows:
			2014		2013		2012
			(In millions)
	Sales and other operating revenues		$	9,576	$	22,652	$	25,517
	Income from discontinued operations before income taxes		$	1,071	$	1,835	$	400
	Current tax provision (benefit)*			—		—		7
	Deferred tax provision (benefit)			389		649		138
	Provision for income taxes			389		649		145
	Income (loss) from discontinued operations, net of income taxes		$	682	$	1,186	$	255
	Less: Net income (loss) attributable to noncontrolling interests			57		-6		20
	Income from discontinued operations attributable to Hess Corporation		$	625	$	1,192	$	235
	*	Substantially all current tax expense relates to foreign taxes on energy trading operations.

Exit_and_Disposal_Costs_Tables

Exit and Disposal Costs (Tables)	12 Months Ended
	Dec. 31, 2014
Restructuring And Related Activities [Abstract]
Components of and Changes in Restructuring Accruals	The following table provides the components of and changes in the Corporation’s restructuring accruals:
		Exploration			Corporate, Interest
		and			and			Discontinued
		Production			Other			Operations			Total
		(In millions)
	Employee Severance
	Balance at January 1, 2014	$	32		$	26		$	113		$	171
	Provision		19			16			41			76
	Payments		(35	)		(26	)		(109	)		(170	)
	Balance at December 31, 2014		16			16			45			77
	Facility and Other Exit Costs
	Balance at January 1, 2014		53			17			48			118
	Provision		(15	)		10			70			65
	Payments, settlements and other		(38	)		(12	)		(108	)		(158	)
	Balance at December 31, 2014		—			15			10			25
	Total restructuring accruals at December 31, 2014	$	16		$	31		$	55		$	102
Financial Statement Classification of Costs and Expenses Associated with Corporation's Restructuring Program	The following table provides the financial statement classification of costs and expenses associated with the Corporation’s restructuring program:
		2014			2013
		(In millions)
	Employee Severance
	Operating costs and expenses	$	5		$	22
	Exploration expenses, including dry holes and lease impairment		3			19
	General and administrative expenses		27			63
	Income from discontinued operations		41			148
	Total employee severance	$	76		$	252
	Facility and Other Exit Costs
	Other, net	$	—		$	8
	Operating costs and expenses		—			1
	General and administrative expenses		(2	)		54
	Depreciation, depletion and amortization		(3	)		16
	Income from discontinued operations		70			141
	Total facility and other exit costs	$	65		$	220

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventories	Inventories at December 31 were as follows:
		2014		2013
		(In millions)
	Crude oil	$	246	$	291
	Natural gas and refined petroleum products		—		618
	Less: LIFO adjustment		—		(339	)
			246		570
	Materials , supplies and merchandise		281		384
	Total inventories	$	527	$	954

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property Plant And Equipment [Abstract]
Components of Property, Plant and Equipment	Property, plant and equipment at December 31 were as follows:
		2014			2013
		(In millions)
	Exploration and Production
	Unproved properties	$	1,468		$	2,460
	Proved properties		4,211			4,121
	Wells, equipment and related facilities		40,649			37,274
			46,328			43,855
	Corporate, Interest and Other		194			2,095
	Total — at cost		46,522			45,950
	Less: Reserves for depreciation, depletion, amortization and lease impairment		19,005			17,179
	Property, plant and equipment — net*	$	27,517		$	28,771
Net Changes in Capitalized Exploratory Well Costs	Capitalized Exploratory Well Costs:  The following table discloses the amount of capitalized exploratory well costs pending determination of proved reserves at December 31, and the changes therein during the respective years:
		2014			2013			2012
		(In millions)
	Beginning balance at January 1	$	2,045		$	2,259		$	2,022
	Additions to capitalized exploratory well costs pending the determination of proved reserves		292			237			407
	Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(629	)		(106	)		(41	)
	Capitalized exploratory well costs charged to expense		(235	)		(267	)		(129	)
	Dispositions and other		(57	)		(78	)		—
	Ending balance at December 31	$	1,416		$	2,045		$	2,259
	Number of wells at end of year		37			50			68
Exploratory Drilling Costs Capitalized	At December 31, 2014, exploratory drilling costs capitalized in excess of one year past the indicated year of completion of drilling were as follows (in millions):
	2013	$	74
	2012		373
	2011		338
	2010		211
	2009 and prior		236
		$	1,232

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]
Changes in Carrying Amount of Goodwill	The changes in the carrying amount of goodwill are as follows:
		2014			2013
		(In millions)
	Beginning balance at January 1	$	1,869		$	2,208
	Acquisitions		115			—
	Dispositions*		(126	)		(339	)
	Ending balance at December 31	$	1,858		$	1,869
	In 2013, the dispositions include $21 million allocated to other assets sold and $76 million that was classified as held for sale and reported within Other current assets.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Changes to Corporation's Asset Retirement Obligations	The following table describes changes to the Corporation’s asset retirement obligations:
		2014			2013
		(In millions)
	Asset retirement obligations at January 1	$	2,772		$	2,661
	Liabilities incurred		63			42
	Liabilities settled or disposed of		(420	)		(576	)
	Accretion expense		136			129
	Revisions of estimated liabilities		263			573
	Foreign currency translation		(91	)		(57	)
	Asset retirement obligations at December 31		2,723			2,772
	Less: Current obligations		442			523
	Long-term obligations at December 31	$	2,281		$	2,249

Debt_and_Interest_Expense_Tabl

Debt and Interest Expense (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-Term Debt	Long‑term debt at December 31 consisted of the following:
			2014		2013
			(In millions)
	Fixed-rate public notes:
	7.0% due 2014		$	—	$	250
	1.3% due 2017			300		—
	8.1% due 2019			999		998
	3.5% due 2024			298		—
	7.9% due 2029			696		695
	7.3% due 2031			747		747
	7.1% due 2033			598		598
	6.0% due 2040			745		745
	5.6% due 2041			1,242		1,242
	Total fixed-rate public notes			5,625		5,275
	Financing obligations associated with floating production system			331		296
	Other fixed-rate notes, weighted average rate 12.9%			—		135
	Project lease financing, weighted average rate 5.1%			—		60
	Fair value adjustments - interest rate hedging			31		30
	Other debt			—		2
	Total debt			5,987		5,798
	Less: Short-term debt and current maturities of long-term debt			68		378
	Total long-term debt		$	5,919	$	5,420
Outstanding Letters of Credit	Outstanding letters of credit at December 31 were as follows:
			2014		2013
			(In millions)
	Committed lines*		$	25	$	274
	Uncommitted lines*			372		136
	Total		$	397	$	410
	*	Committed and uncommitted lines have expiration dates through 2016.

Sharebased_Compensation_Tables

Share-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-based Compensation Expense	Share‑based compensation expense consisted of the following:
			Before Income Taxes										After Income Taxes
			2014			2013				2012			2014		2013			2012
			(In millions)
	Restricted stock		$	62		$	31			$	57		$	39	$	19		$	35
	Stock options			2			13				34			1		8			21
	Performance share units			19			10				8			12		6			5
	Total*		$	83		$	54			$	99		$	52	$	33		$	61
	*	Includes pre‑tax share‑based compensation expense included in Income from continuing operations of approximately $87 million, $60 million and $83 million for 2014, 2013 and 2012, respectively.
Summary of Share-based Compensation Activity
	The Corporation’s share‑based compensation activity consisted of the following:
			Performance Share Units							Stock Options					Restricted Stock
			Performance			Weighted-				Options			Weighted-		Shares of			Weighted-
			Share Units			Average Fair							Average		Restricted			Average Price
						Value on Date							Exercise Price		Common			on Date of
						of Grant							per Share		Stock			Grant
			(In thousands)							(In thousands)					(In thousands)
	Outstanding at January 1, 2014			635		$	89.45				10,141		$	63.08		2,865		$	69.36
	Granted			298			90.32				163			80.35		1081			81.2
	Exercised			—			—				(3,327	)		54.99		—			—
	Vested			—			—				—			—		(510	)		82.42
	Forfeited			(133	)		88.6				(211	)		85.07		(535	)		68.74
	Outstanding at December 31, 2014			800		$	89.91				6,766		$	66.79		2,901		$	71.58
Summary of Information Regarding Outstanding and Exercisable Stock Options	The table below summarizes information regarding the outstanding and exercisable stock options as of December 31, 2014:
				Outstanding Options								Exercisable Options
				Options		Weighted-Average Remaining Contractual Life			Weighted-Average Exercise Price per Share			Options		Weighted-Average Exercise Price per Share
	Range of Exercise Prices
				(In thousands)		(Years)						(In thousands)
	$20.00 – $40.00			65		1			$         29.96			65	$	29.96
	$40.01 – $50.00			684		2			49.42			681		49.44
	$50.01 – $60.00			1,927		4			55.08			1,921		55.08
	$60.01 – $80.00			1,302		4			60.68			1,302		60.68
	$80.01 – $120.00			2,788		5			82.85			2,625		83.00
				6,766		4			$         66.79			6,594	$	66.47
Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards	The following weighted average assumptions were utilized to estimate the fair value of PSU awards:
			2014			2013
	Risk free interest rate			0.65	%		0.36	%
	Stock price volatility			0.359			0.359
	Contractual term in years			3			3
	Grant date price of Hess common stock		$	80.35		$	69.49

Retirement_Plans_Tables

Retirement Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Compensation And Retirement Disclosure [Abstract]
Funded Status of Pension and Postretirement Medical Plans	The following table summarizes the Corporation’s benefit obligations and the fair value of plan assets and shows the funded status of the pension and postretirement medical plans:
			Funded						Unfunded						Postretirement
			Pension Plans						Pension Plan						Medical Plan
			2014			2013			2014			2013			2014			2013
			(In millions)
	Change in benefit obligation
	Balance at January 1		$	1,957		$	2,110		$	253		$	234		$	97		$	134
	Service cost			45			61			12			12			4			4
	Interest cost			91			82			9			7			3			3
	Actuarial (gain) loss (a)			470			(139	)		61			28			(4	)		(4	)
	Benefit payments (b)			(77	)		(69	)		(57	)		(20	)		(6	)		(5	)
	Plan curtailments (c)			(3	)		(103	)		—			(8	)		—			(35	)
	Special termination benefits			2			5			—			—			—			—
	Foreign currency exchange rate changes			(35	)		10			—			—			—			—
	Balance at December 31			2,450			1,957			278			253			94			97
	Change in fair value of plan assets
	Balance at January 1			2,145			1,763			—			—			—			—
	Actual return on plan assets			151			292			—			—			—			—
	Employer contributions			68			146			56			20			6			5
	Benefit payments (b)			(77	)		(69	)		(56	)		(20	)		(6	)		(5	)
	Foreign currency exchange rate changes			(36	)		13			—			—			—			—
	Balance at December 31			2,251			2,145			—			—			—			—
	Funded status (plan assets greater (less) than benefit obligations) at December 31			(199	)		188			(278	)		(253	)		(94	)		(97	)
	Unrecognized net actuarial (gains) losses			859			405			135			108			(5	)		(2	)
	(a)	The change in discount rate and mortality assumptions in 2014 resulted in total actuarial losses of approximately $330 million and $125 million, respectively.
	(b)	Benefit payments include lump-sum settlement payments of $55 million in 2014.
	(c)	During the first quarter of 2013, the Corporation’s pension and other postretirement plans were impacted by a significant reduction in the expected future service from active participants due to the Corporation’s announced asset sales program.
Amounts Recognized in Consolidated Balance Sheet	Amounts recognized in the Consolidated Balance Sheet at December 31 consisted of the following:
			Funded						Unfunded						Postretirement
			Pension Plans						Pension Plan						Medical Plan
			2014			2013			2014			2013			2014			2013
			(In millions)
	Pension asset / (accrued benefit liability)		$	(199	)	$	188		$	(278	)	$	(253	)	$	(94	)	$	(97	)
	Accumulated other comprehensive loss, pre-tax*			859			405			135			108			(5	)		(2	)
	*	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) for these retirement plans was $652 million at December 31, 2014 and $342 million at December 31, 2013.
Components of Net Periodic Benefit Cost	Components of net periodic benefit cost for funded and unfunded pension plans and the postretirement medical plan consisted of the following:
			Pension Plans									Postretirement Medical Plan
			2014			2013			2012			2014			2013			2012
			(In millions)
	Service cost		$	57		$	73		$	74		$	4		$	4		$	7
	Interest cost			100			89			88			3			3			5
	Expected return on plan assets			(161	)		(141	)		(116	)		—			—			—
	Amortization of unrecognized net actuarial losses			31			61			83			—			1			2
	Settlement loss			24			—			9			—			—			—
	Curtailment loss			—			1			—			—			—			—
	Special termination benefit recognized			1			5			—			—			—			—
	Net periodic benefit cost		$	52		$	88		$	138		$	7		$	8		$	14
Weighted Average Actuarial Assumptions Used in Calculation of Pension Plans	The weighted average actuarial assumptions used by the Corporation’s funded and unfunded pension plans were as follows:
			2014			2013			2012
	Weighted average assumptions used to determine benefit obligations at December 31
	Discount rate			3.8	%		4.6	%		3.8	%
	Rate of compensation increase			5			4.4			4.3
	Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31
	Discount rate			4.6			4			4.3
	Expected return on plan assets			7.5			7.5			7.5
	Rate of compensation increase			4.4			4.3			4.3
Actuarial Assumptions Used by Corporation's Postretirement Medical Plan	The actuarial assumptions used by the Corporation’s postretirement medical plan were as follows:
			2014			2013			2012
	Assumptions used to determine benefit obligations at December 31
	Discount rate			3.1	%		3.6	%		3.1	%
	Initial health care trend rate			6.8	%		7.1	%		7.3	%
	Ultimate trend rate			4.5	%		4.6	%		4.8	%
	Year in which ultimate trend rate is reached			2029			2027			2022
Fair Value of Plan's Financial Assets	The following tables provide the fair value of the financial assets of the funded pension plans as of December 31, 2014 and 2013 in accordance with the fair value measurement hierarchy described in Note 1, Summary of Significant Accounting Policies in the Notes to the Consolidated Financial Statements:
			Level 1			Level 2			Level 3			Total
			(In millions)
	December 31, 2014
	Cash and short-term investment funds		$	6		$	47		$	—		$	53
	Equities:
	U.S. equities (domestic)			719			—			—			719
	International equities (non-U.S.)			72			177			—			249
	Global equities (domestic and non-U.S.)			10			218			—			228
	Fixed income:
	Treasury and government issued (a)			—			222						222
	Government related (b)			—			7			1			8
	Mortgage-backed securities (c)			—			147			1			148
	Corporate			3			137						140
	Other:
	Hedge funds			—			—			302			302
	Private equity funds			—			—			105			105
	Real estate funds			12			—			48			60
	Diversified commodities funds			—			17			—			17
			$	822		$	972		$	457		$	2,251
	December 31, 2013
	Cash and short-term investment funds		$	3		$	72		$	—		$	75
	Equities:
	U.S. equities (domestic)			729			—			—			729
	International equities (non-U.S.)			81			171			—			252
	Global equities (domestic and non-U.S.)			8			208			—			216
	Fixed income:
	Treasury and government issued (a)			—			169			1			170
	Government related (b)			—			9			—			9
	Mortgage-backed securities (c)			—			109			1			110
	Corporate			2			124			1			127
	Other:
	Hedge funds			—			—			291			291
	Private equity funds			—			—			89			89
	Real estate funds			10			—			47			57
	Diversified commodities funds			—			20			—			20
			$	833		$	882		$	430		$	2,145
	(a)	Includes securities issued and guaranteed by U.S. and non‑U.S. governments.
	(b)	Primarily consists of securities issued by governmental agencies and municipalities.
	(c)	Comprised of U.S. residential and commercial mortgage-backed securities.
Fair Value Based on Level 3 Inputs Held by Institutional Funds	The following tables provide changes in financial assets that are measured at fair value based on Level 3 inputs that are held by institutional funds classified as:
									Private			Real
			Fixed			Hedge			Equity			Estate
			Income*			Funds			Funds			Funds			Total
			(In millions)
	Balance at January 1, 2013		$	2		$	255		$	75		$	45		$	377
	Actual return on plan assets			—			26			11			2			39
	Purchases, sales or other settlements			1			10			3			—			14
	Net transfers in (out) of Level 3			—			—			—			—			—
	Balance at December 31, 2013			3			291			89			47			430
	Actual return on plan assets			—			9			15			—			24
	Purchases, sales or other settlements			(1	)		2			1			1			3
	Net transfers in (out) of Level 3			—			—			—			—			—
	Balance at December 31, 2014		$	2		$	302		$	105		$	48		$	457
	*	Fixed Income includes treasury and government issued, government related, mortgage‑backed and corporate securities.
Estimated Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan	Estimated future benefit payments by the funded and unfunded pension plans and the postretirement medical plan, which reflect expected future service, are as follows (in millions):
	2015		$	157
	2016			112
	2017			118
	2018			121
	2019			129
	Years 2020 to 2024			694

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Provision (Benefit) for Income Taxes from Continuing Operations	The provision (benefit) for income taxes from continuing operations consisted of:
			2014			2013			2012
			(In millions)
	United States
	Federal
	Current		$	(1	)	$	8		$	30
	Deferred			156			103			(435	)
	State			57			9			31
				212			120			(374	)
	Foreign
	Current			453			941			2,012
	Deferred			79			186			(224	)
				532			1,127			1,788
	Total			744			1,247			1,414
	Adjustment of deferred taxes for foreign income tax law changes*			—			(682	)		115
	Total provision for income taxes		$	744		$	565		$	1,529
	*	The reported amount for 2013 reflects $674 million for the effect of the Denmark hydrocarbon income tax law change to the Chapter 3A regime from the Chapter 3 regime in December 2013 and $8 million for the effect of a change in Norway’s hydrocarbon and base corporate income tax rates in December 2013. In 2012, the reported amount reflects the effect of the UK supplementary income tax rate change in July 2012.
Income From Continuing Operations Before Income Taxes	Income from continuing operations before income taxes consisted of the following:
			2014			2013			2012
			(In millions)
	United States (a)		$	676		$	580		$	(608	)
	Foreign			1,760			4,021			3,945
	Total income from continuing operations before income taxes		$	2,436		$	4,601		$	3,337
	(a)	Includes substantially all of the Corporation’s interest expense, corporate expense and the results of commodity hedging activities.
Components of Deferred Tax Liabilities and Deferred Tax Assets	The components of deferred tax liabilities and deferred tax assets at December 31 were as follows:
			2014			2013
			(In millions)
	Deferred tax liabilities
	Property, plant and equipment and investments		$	(5,361	)	$	(5,581	)
	Other			(269	)		(155	)
	Total deferred tax liabilities			(5,630	)		(5,736	)
	Deferred tax assets
	Net operating loss carryforwards			3,010			2,726
	Tax credit carryforwards			193			161
	Property, plant and equipment and investments			2,245			2,643
	Accrued compensation, deferred credits and other liabilities			449			982
	Asset retirement obligations			1,421			1,516
	Other			261			216
	Total deferred tax assets			7,579			8,244
	Valuation allowances			(1,416	)		(1,519	)
	Total deferred tax assets, net of valuation allowances			6,163			6,725
	Net deferred tax assets		$	533		$	989
Deferred Tax Assets and Liabilities, Net	In the Consolidated Balance Sheet, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:
			2014			2013
			(In millions)
	Other current assets		$	373		$	963
	Deferred income taxes (long-term asset)			2,169			2,319
	Accrued liabilities			—			(1	)
	Deferred income taxes (long-term liability)			(2,009	)		(2,292	)
	Net deferred tax assets		$	533		$	989
Difference Between Corporation's Effective Income Tax Rate from Continuing Operations and U.S. Statutory Rate	The difference between the Corporation’s effective income tax rate from continuing operations and the U.S. statutory rate is reconciled below:
			2014			2013			2012
	U.S. statutory rate			35	%		35	%		35	%
	Effect of foreign operations*			1			6.9			12.5
	State income taxes, net of Federal income tax			1.5			0.1			0.6
	Change in enacted tax laws			—			(14.8	)		3.4
	Gains on asset sales, net			(8.3	)		(15.6	)		(5.4	)
	Other			1.3			0.7			(0.3	)
	Total			30.5	%		12.3	%		45.8	%
	*	The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the suspension of operations in Libya for a portion of 2013 and most of 2014.
Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits	Below is a reconciliation of the gross beginning and ending amounts of unrecognized tax benefits:
			2014			2013
			(In millions)
	Balance at January 1		$	570		$	523
	Additions based on tax positions taken in the current year			42			161
	Additions based on tax positions of prior years			70			2
	Reductions based on tax positions of prior years			(76	)		(96	)
	Reductions due to settlements with taxing authorities			(3	)		(19	)
	Reductions due to lapses in statutes of limitation			—			(1	)
	Balance at December 31		$	603		$	570

Outstanding_and_Weighted_Avera1

Outstanding and Weighted Average Common Shares (Tables)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Changes in Corporation's Outstanding Common Shares	The following table provides the changes in the Corporation’s outstanding common shares:
			2014			2013			2012
			(In millions)
	Balance at January 1			325.3			341.5			340
	Activity related to restricted common stock awards, net			0.6			0.8			1.3
	Stock options exercised			3.3			2.3			0.2
	Shares repurchased*			(43.4	)		(19.3	)		—
	Balance at December 31			285.8			325.3			341.5
		*  See Note 16, Share Repurchase Plan in the Notes to the Consolidated Financial Statements.
Basic and Diluted Earnings Per Share	The following table presents the calculation of basic and diluted earnings per share:
			2014			2013			2012
			(In millions)
	Income from continuing operations, net of income taxes		$	1,692		$	4,036		$	1,808
	Less: Net income attributable to noncontrolling interests			—			176			18
	Net income from continuing operations attributable to Hess Corporation			1,692			3,860			1,790
	Income from discontinued operations, net of income taxes			682			1,186			255
	Less: Net income (loss) attributable to noncontrolling interests			57			(6	)		20
	Net income from discontinued operations attributable Hess Corporation			625			1,192			235
	Net income attributable to Hess Corporation		$	2,317		$	5,052		$	2,025
	Weighted average common shares outstanding:
	Basic			303.7			336.6			338.4
	Effect of dilutive securities
	Restricted common stock			1.5			1.4			1.1
	Stock options			1.8			1.7			0.8
	Performance share units			0.7			1.2			—
	Diluted			307.7			340.9			340.3
	Net income attributable to Hess Corporation per share:
	Basic:
	Continuing operations		$	5.57		$	11.47		$	5.29
	Discontinued operations			2.06			3.54			0.69
	Net income per share		$	7.63		$	15.01		$	5.98
	Diluted:
	Continuing operations		$	5.5		$	11.33		$	5.26
	Discontinued operations			2.03			3.49			0.69
	Net income per share		$	7.53		$	14.82		$	5.95

Leased_Assets_Tables

Leased Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Future Minimum Rental Payments	At December 31, 2014, future minimum rental payments applicable to non‑cancelable operating leases with remaining terms of one year or more (other than oil and gas property leases) are as follows (in millions):
	2015	$	773
	2016		627
	2017		422
	2018		348
	2019		303
	Remaining years		345
	Total minimum lease payments		2,818
	Less: Income from subleases		36
	Net minimum lease payments	$	2,782
Rental Expense	Rental expense was as follows:
		2014		2013		2012
		(In millions)
	Total rental expense	$	248	$	355	$	375
	Less: Income from subleases		17		15		15
	Net rental expense	$	231	$	340	$	360

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Financial Data by Operating Segment for Continuing Operations	The following table presents operating segment financial data for continuing operations
			Exploration		Corporate,			Total
			and		Interest
			Production		and Other
			(In millions)
	2014
	Operating revenues		$	10,737	$	—		$	10,737
	Net income (loss) from continuing operations attributable to Hess Corporation		$	2,098	$	(406	)	$	1,692
	Interest expense		$	—	$	323		$	323
	Depreciation, depletion and amortization			3,210		14			3,224
	Provision (benefit) for income taxes			996		(252	)		744
	Investments in affiliates			151		—			151
	Identifiable assets			36,512		908			37,420
	Capital expenditures			5,221		53			5,274
	2013
	Operating revenues		$	11,905	$	—		$	11,905
	Net Income (loss) from continuing operations attributable to Hess Corporation		$	4,303	$	(443	)	$	3,860
	Interest expense		$	—	$	406		$	406
	Depreciation, depletion and amortization			2,671		16			2,687
	Asset impairments			289		—			289
	Provision (benefit) for income taxes			831		(266	)		565
	Investments in affiliates			109		397			506
	Identifiable assets			37,863		1,352			39,215
	Capital expenditures			5,709		58			5,767
	2012
	Operating revenues		$	12,245	$	—		$	12,245
	Net income (loss) from continuing operations attributable to Hess Corporation		$	2,212	$	(422	)	$	1,790
	Interest expense		$	—	$	419		$	419
	Depreciation, depletion and amortization			2,853		13			2,866
	Asset impairments			582		—			582
	Provision (benefit) for income taxes			1,793		(264	)		1,529
	Investments in affiliates			75		198			273
	Identifiable assets			37,687		813			38,500
	Capital expenditures			7,676		6			7,682
Financial Information by Major Geographic Area	The following table presents financial information by major geographic area:
			United		Europe			Africa		Asia and		Corporate,			Total
			States							Other		Interest
										Countries		and Other
			(In millions)
	2014
	Operating revenues		$	6,270	$	1,557		$	2,002	$	908	$	—		$	10,737
	Net income (loss) from continuing operations attributable to Hess Corporation			656		226			545		671		(406	)		1,692
	Depreciation, depletion and amortization			1,751		683			487		289		14			3,224
	Provision (benefit) for income taxes			446		91			435		24		(252	)		744
	Identifiable assets			18,472		7,800			3,049		7,191		908			37,420
	Property, plant and equipment (net) (a)			15,595		6,339			2,235		3,232		116			27,517
	Capital expenditures			3,467		524			399		831		53			5,274
	2013
	Operating revenues		$	6,076	$	1,337		$	2,736	$	1,756	$	—		$	11,905
	Net income (loss) from continuing operations attributable to Hess Corporation			777		2,051			594		881		(443	)		3,860
	Depreciation, depletion and amortization			1,393		484			518		276		16			2,687
	Asset impairments			—		—			—		289		—			289
	Provision (benefit) for income taxes			495		(646	)		767		215		(266	)		565
	Identifiable assets			18,617		9,032			3,198		7,016		1,352			39,215
	Property, plant and equipment (net) (a)			14,873		7,475			2,310		2,899		193			27,750
	Capital expenditures			3,613		689			578		829		58			5,767
	2012
	Operating revenues		$	5,294	$	2,530		$	2,484	$	1,937	$	—		$	12,245
	Net income (loss) from continuing operations attributable to Hess Corporation			438		1,010			602		162		(422	)		1,790
	Depreciation, depletion and amortization			1,406		466			529		452		13			2,866
	Asset impairments			432		119			—		31		—			582
	Provision (benefit) for income taxes			267		376			905		245		(264	)		1,529
	Identifiable assets			16,403		8,957			3,811		8,516		813			38,500
	Property, plant and equipment (net) (a)			12,893		8,172			2,516		3,875		86			27,542
	Capital expenditures			4,620		1,330			733		993		6			7,682
	(a)	Of the total Europe, Property, plant and equipment (net), Norway represented $5,246 million, $6,348 million and $6,426 million in 2014, 2013, and 2012, respectively.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	The following table presents the Corporation’s related party transactions:
			2014		2013			2012
			(In millions)
	Purchases:
	HOVENSA (a)		$	—	$	—		$	145
	Bayonne Energy Center LLC (b)			—		38			20
	Sales:
	WilcoHess (c)			211		2,828			3,058
	HOVENSA			31		90			191
	(a)	The Corporation ceased purchasing refined products from HOVENSA following the closure of HOVENSA’s refinery in January 2012.
	(b)	Represents purchases of electricity from this 50% owned joint venture under a tolling agreement.
	(c)	The Corporation acquired its partners’ 56% interest in WilcoHess in January 2014.
Corporation's Related Party Accounts Receivable (Payable)	The following table presents the Corporation’s related party accounts receivable (payable) at December 31:
			2014		2013
			(In millions)
	WilcoHess		$	—	$	114
	Bayonne Energy Center LLC			—		(4	)

Financial_Risk_Management_and_1

Financial Risk Management and Trading Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Netting Arrangements on Physical and Financial Derivative Assets and (Liabilities)	The following table provides information about the effect of netting arrangements on the presentation of the Corporation’s physical and financial derivative assets and (liabilities) that are measured at fair value, with the effect of single counterparty multilateral netting being included in column (v):
						Gross Amounts Offset in the
						Consolidated Balance Sheet
			Gross Amounts			Physical			Cash Collateral (a)			Net Amounts			Gross Amounts			Net Amounts
						Derivative and						Presented in the			Not Offset in the
						Financial						Consolidated			Consolidated
						Instruments						Balance Sheet			Balance Sheet
			(i)			(ii)			(iii)			(iv)=)+(ii)+(iii)			(v)			(vi)=v)+(v)
			(In millions)
	December 31, 2014
	Assets
	Derivative contracts
	Commodity		$	7,465		$	(6,664	)	$	(36	)	$	765		$	(3	)	$	762
	Interest rate and other			76			(7	)		(1	)		68			(1	)		67
	Counterparty netting			—			(63	)		—			(63	)		—			(63	)
	Total derivative contracts		$	7,541		$	(6,734	)	$	(37	)	$	770		$	(4	)	$	766
	Liabilities
	Derivative contracts
	Commodity		$	(7,871	)	$	6,664		$	299		$	(908	)	$	3		$	(905	)
	Interest rate and other			(13	)		7			3			(3	)		1			(2	)
	Counterparty netting			—			63			—			63			—			63
	Total derivative contracts		$	(7,884	)	$	6,734		$	302		$	(848	)	$	4		$	(844	)
	December 31, 2013 (b)
	Assets
	Derivative contracts
	Commodity		$	3,086		$	(1,867	)	$	(79	)	$	1,140		$	(41	)	$	1,099
	Interest rate and other			51			(10	)		—			41			(3	)		38
	Counterparty netting			—			(206	)		—			(206	)		—			(206	)
	Total derivative contracts		$	3,137		$	(2,083	)	$	(79	)	$	975		$	(44	)	$	931
	Liabilities
	Derivative contracts
	Commodity		$	(3,212	)	$	1,867		$	168		$	(1,177	)	$	41		$	(1,136	)
	Other			(12	)		10			—			(2	)		3			1
	Counterparty netting			—			206			—			206			—			206
	Total derivative contracts		$	(3,224	)	$	2,083		$	168		$	(973	)	$	44		$	(929	)
	(a)	All cash collateral was offset in the Consolidated Balance Sheet.
	(b)	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
Gross and Net Fair Values of Corporate and Energy Marketing Risk Management and Trading Derivative Instruments	The table below reflects the gross and net fair values of the risk management and trading derivative instruments and, at December 31, 2013 also includes energy marketing risk management derivative instruments:
			Accounts			Accounts
			Receivable			Payable
			(In millions)
	December 31, 2014
	Derivative contracts designated as hedging instruments
	Commodity		$	—		$	—
	Interest rate and other			39			(2	)
	Total derivative contracts designated as hedging instruments			39			(2	)
	Derivative contracts not designated as hedging instruments (a)
	Commodity			7,465			(7,871	)
	Foreign exchange			31			—
	Other			6			(11	)
	Total derivative contracts not designated as hedging instruments			7,502			(7,882	)
	Gross fair value of derivative contracts			7,541			(7,884	)
	Master netting arrangements			(6,734	)		6,734
	Cash collateral (received) posted			(37	)		302
	Net fair value of derivative contracts		$	770		$	(848	)
	December 31, 2013 (b)
	Derivative contracts designated as hedging instruments
	Commodity		$	11		$	(3	)
	Interest rate and other			36			(1	)
	Total derivative contracts designated as hedging instruments			47			(4	)
	Derivative contracts not designated as hedging instruments (a)
	Commodity			3,075			(3,209	)
	Foreign exchange			2			(3	)
	Other			13			(8	)
	Total derivative contracts not designated as hedging instruments			3,090			(3,220	)
	Gross fair value of derivative contracts			3,137			(3,224	)
	Master netting arrangements			(2,083	)		2,083
	Cash collateral (received) posted			(79	)		168
	Net fair value of derivative contracts		$	975		$	(973	)
	•	Includes trading derivatives and derivatives used for risk management
	•	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business
Fair Values for Corporation's Net Physical Derivative and Financial Assets and (Liabilities)	The following table provides the Corporation’s net physical derivative and financial assets and (liabilities) that are measured at fair value based on this hierarchy:
			Level 1			Level 2			Level 3			Counterparty			Collateral			Balance
												netting
			(In millions)
	December 31, 2014
	Assets
	Derivative contracts
	Commodity		$	755		$	390		$	114		$	(458	)	$	(36	)	$	765
	Interest rate and other			(1	)		70			—			—			(1	)		68
	Collateral and counterparty netting			(43	)		(20	)		—			—			—			(63	)
	Total derivative contracts			711			440			114			(458	)		(37	)		770
	Other assets measured at fair value on a recurring basis			27			—			—			—			—			27
	Total assets measured at fair value on a recurring basis		$	738		$	440		$	114		$	(458	)	$	(37	)	$	797
	Liabilities
	Derivative contracts
	Commodity		$	(338	)	$	(1,265	)	$	(62	)	$	458		$	299		$	(908	)
	Other			(3	)		(1	)		(2	)		—			3			(3	)
	Collateral and counterparty netting			43			20			—			—			—			63
	Total derivative contracts			(298	)		(1,246	)		(64	)		458			302			(848	)
	Other liabilities measured at fair value on a recurring basis			(40	)		—			—			—			—			(40	)
	Total liabilities measured at fair value on a recurring basis		$	(338	)	$	(1,246	)	$	(64	)	$	458		$	302		$	(888	)
	Other fair value measurement disclosures     Long-term debt (a)		$	—		$	(7,003	)	$	—		$	—		$	—		$	(7,003	)
	December 31, 2013 (b)
	Assets
	Derivative contracts
	Commodity		$	254		$	579		$	494		$	(108	)	$	(79	)	$	1,140
	Interest rate and other			2			37			3			(1	)		—			41
	Collateral and counterparty netting			(15	)		(191	)		—			—			—			(206	)
	Total derivative contracts			241			425			497			(109	)		(79	)		975
	Other assets measured at fair value on a recurring basis			—			—			—			—			—			—
	Total assets measured at fair value on a recurring basis		$	241		$	425		$	497		$	(109	)	$	(79	)	$	975
	Liabilities
	Derivative contracts
	Commodity		$	(97	)	$	(1,071	)	$	(285	)	$	108		$	168		$	(1,177	)
	Other			—			(3	)		—			1			—			(2	)
	Collateral and counterparty netting			15			191			—			—			—			206
	Total derivative contracts			(82	)		(883	)		(285	)		109			168			(973	)
	Other liabilities measured at fair value on a recurring basis			(31	)		—			—			—			—			(31	)
	Total liabilities measured at fair value on a recurring basis		$	(113	)	$	(883	)	$	(285	)	$	109		$	168		$	(1,004	)
	Other fair value measurement disclosures     Long-term debt (a)		$	—		$	(6,641	)	$	—		$	—		$	—		$	(6,641	)
	(a)	Long-term debt, including current maturities, had a carrying value of $5,987 million and $5,798 million at December 31, 2014 and 2013, respectively.
	(b)	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
Net Transfers into and Out of Each Level of Fair Value Hierarchy	The following table provides total net transfers into and out of each level of the fair value hierarchy:
			2014			2013
			(In millions)
	Transfers into Level 1		$	25		$	3
	Transfers out of Level 1			(47	)		76
			$	(22	)	$	79
	Transfers into Level 2		$	25		$	(113	)
	Transfers out of Level 2			(128	)		88
			$	(103	)	$	(25	)
	Transfers into Level 3		$	105		$	(85	)
	Transfers out of Level 3			20			31
			$	125		$	(54	)
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) primarily related to commodities that are measured at fair value based on Level 3 inputs:
			2014			2013
			(In millions)
	Balance at January 1		$	212		$	141
	Unrealized pre-tax gains (losses)
	Included in earnings (a)			(298	)		175
	Purchases (b)			31			45
	Sales (b)			(24	)		(34	)
	Settlements (c)			4			(61	)
	Transfers into Level 3			105			(85	)
	Transfers out of Level 3			20			31
	Balance at December 31		$	50		$	212
	(a)	The unrealized pre‑tax gains and losses included in earnings were reflected in Income from discontinued operations in the Statement of Consolidated Income.
	(b)	Purchases and sales primarily represent option premiums paid or received, respectively, during the reporting period and were reflected in Income from discontinued operations in the Statement of Consolidated Income.
	(c)	Settlements represent realized gains (losses) on derivatives settled during the reporting period and were reflected in Income from discontinued operations in the Statement of Consolidated Income.
Commodity Contracts with a Fair Value	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 in the table below represent full contract prices. Significant changes in any of the inputs, independently or correlated, may result in a different fair value.
			Unit of			Range /
			Measurement			Weighted Average
	December 31, 2014
	Assets
	Commodity contracts with a fair value of $114 million
	Contract prices
	Crude oil and refined petroleum products			$ / bbl (a)		$	36.27 - 122.66 / 65.63
	Electricity			$ / MWH (b)		$	38.80 - 71.69 / 57.22
	Basis prices
	Natural gas			$ / MMBTU (c)		$	(0.61) - 13.50 / 6.19
	Contract volatilities
	Crude oil and refined petroleum products			%			32.00 - 45.00 / 43.00
	Natural gas			%			19.00 - 53.00 / 40.00
	Liabilities
	Commodity contracts with a fair value of $62 million
	Contract prices
	Crude oil and refined petroleum products			$ / bbl (a)		$	36.27 - 85.40 / 69.54
	Basis prices
	Natural gas			$ / MMBTU (c)		$	2.84 - 4.45 / 2.94
	Contract volatilities
	Crude oil and refined petroleum products			%			32.00 - 45.00 / 41.00
	Natural gas			%			23.00 - 53.00 / 41.00
			Unit of			Range /
			Measurement			Weighted Average
	December 31, 2013 (b)
	Assets
	Commodity contracts with a fair value of $494 million
	Contract prices
	Crude oil and refined petroleum products			$ / bbl (a)		$	78.45 - 228.86 / 118.68
	Electricity			$ / MWH (b)		$	19.52 -165.75 / 45.76
	Basis prices
	Natural gas			$ / MMBTU (c)		$	(4.99) - 18.10 / 0.23
	Contract volatilities
	Crude oil and refined petroleum products			%			16.00 - 18.00 / 17.00
	Natural gas			%			17.00 - 35.00 / 22.00
	Electricity			%			16.00 - 36.00 / 23.00
	Liabilities
	Commodity contracts with a fair value of $285 million
	Contract prices
	Crude oil and refined petroleum products			$ / bbl (a)		$	57.45 - 183.89 / 122.54
	Electricity			$ / MWH (b)		$	26.48 - 155.33 / 43.12
	Basis prices
	Natural gas			$ / MMBTU (c)		$	(1.90) - 18.00 / (0.62)
	Contract volatilities
	Crude oil and refined petroleum products			%			16.00 - 17.00 / 17.00
	Natural gas			%			34.00 - 35.00 / 35.00
	Electricity			%			16.00 – 36.00 / 22.00
	(a)	Price per barrel.
	(b)	Price per megawatt hour.
	(c)	Price per million British thermal unit
	(d	Assets and liabilities in 2013 include amounts relating to the divested energy marketing business.
Financial Risk Management [Member]
Gross Volumes of Corporation's Derivative Contracts Outstanding	The gross volumes of the financial risk management derivative contracts outstanding at December 31, were as follows:
			2014			2013
	Commodity, primarily crude oil (millions of barrels)			—			9
	Foreign exchange (millions of USD*)		$	1,189		$	220
	Interest rate swaps (millions of USD)		$	1,300		$	865
Corporate Risk Management [Member]
Net Realized and Unrealized Pre-Tax Gains (Losses) on Derivative Contracts Not Designated as Hedges	Net realized and unrealized pre‑tax gains (losses) on derivative contracts used in Corporate Risk Management activities and not designated as hedges amounted to the following:
			2014			2013			2012
			(In millions)
	Commodity		$	—		$	—		$	1
	Foreign exchange			117			(39	)		43
	Total		$	117		$	(39	)	$	44
Trading Activities [Member]
Gross Volumes of Corporation's Derivative Contracts Outstanding	The gross volumes of derivative contracts outstanding related to trading activities at December 31, were as follows:
			2014			2013
	Commodity
	Crude oil and refined petroleum products (millions of barrels)			1,396			1,815
	Natural gas (millions of mcf)			2,224			2,735
	Electricity (millions of megawatt hours)			1			1
	Foreign exchange (millions of USD)		$	77		$	52
	Interest rate (millions of USD)		$	29		$	—
	Equity securities (millions of shares)			5			11
Net Realized and Unrealized Pre-Tax gains (Losses) Reflected in Sales and Other Operating Revenues in Statement of Consolidated Income	Pre‑tax unrealized and realized gains (losses) recorded in the Statement of Consolidated Income from trading activities amounted to the following:
			2014			2013			2012
			(In millions)
	Commodity		$	168		$	78		$	104
	Foreign exchange			2			—			3
	Other			32			1			10
	Total *		$	202		$	79		$	117
	*	The unrealized pre‑tax gains and losses included in earnings were reflected in Income from discontinued operations in the Statement of Consolidated Income.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014
	ReportingUnit
Summary Of Significant Accounting Policies [Line Items]
Ownership in controlling entities	More than a 50% voting interest
Voting interest in trading partnership	50.00%
Impairment of Long-Lived Assets to be Disposed of	$0
Number of reporting units in E&P	2
Goodwill, Impairment Loss	0
Prior service costs and actuarial gains and losses in excess of greater of benefit obligation or market value of assets represented as percentage	10.00%
Estimated remediation liabilities	$80,000,000
Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Investments in affiliated companies	20.00%
Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Investments in affiliated companies	50.00%
HOVENSA [Member]
Summary Of Significant Accounting Policies [Line Items]
Investments in affiliated companies	50.00%

Discontinued_Operations_Summar

Discontinued Operations - Summary of Sales and Other Operating Revenues and Income from Discontinued Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of income taxes	$682	$1,186	$255
Less: Net income (loss) attributable to noncontrolling interests	57	-6	20
Income from discontinued operations, net of income taxes	625	1,192	235
Discontinued Operations [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Sales and other operating revenues	9,576	22,652	25,517
Income from discontinued operations before income taxes	1,071	1,835	400
Current tax provision (benefit)			7	[1]
Deferred tax provision (benefit)	389	649	138
Provision for income taxes, discontinued operations	$389	$649	$145
[1]	Substantially all current tax expense relates to foreign taxes on energy trading operations.

Discontinued_Operations_Additi

Discontinued Operations - Additional Information (Detail) (USD $)	1 Months Ended		12 Months Ended			1 Months Ended
	Sep. 30, 2014	Nov. 30, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2014
	Lease
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Goodwill included in the divested businesses' net book value			$126,000,000	$339,000,000
Effect of LIFO inventory liquidation on income, Before tax	275,000,000	678,000,000			165,000,000
Effect of LIFO inventory liquidation on income, After tax	171,000,000	414,000,000			104,000,000
Impairment, environmental, severance and business exit charges, pre-tax	308,000,000	523,000,000			43,000,000
Impairment, environmental, severance and business exit charges, after-tax	202,000,000	334,000,000			33,000,000
Charge related to termination of lease contracts and the purchase of retail gasoline stations, before tax	115,000,000
Charge related to termination of lease contracts and the purchase of retail gasoline stations, after tax	72,000,000
Number of retail gasoline station leases, buyout	180
Goodwill acquired during period			115,000,000
WilcoHess [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Percentage of equity interest						56.00%
Equity interest on fair value						44.00%
Business acquisition, cost of acquired entity, purchase price						290,000,000
Adjustments of equity investment to fair value, pre-tax gain						39,000,000
Adjustments of equity investment to fair value, after income taxes						24,000,000
Goodwill acquired during period						115,000,000
Discontinued Operations [Member] | U.S. East Coast Terminal Network, St. Lucia Terminal and Related Businesses [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Consideration from sale of retail business				1,000,000,000
Gain (loss) on asset sale, pre-tax				739,000,000
Gain (loss) on asset sale, after-tax				531,000,000
Discontinued Operations [Member] | Energy Marketing Business [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Consideration from sale of retail business		1,200,000,000
Gain (loss) on asset sale, pre-tax		761,000,000
Gain (loss) on asset sale, after-tax		464,000,000
Discontinued Operations [Member] | Retail Business Disposal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Consideration from sale of retail business	2,800,000,000
Gain (loss) on asset sale, pre-tax	954,000,000
Gain (loss) on asset sale, after-tax	602,000,000
Goodwill included in the divested businesses' net book value	$115,000,000

Dispositions_Additional_Inform

Dispositions - Additional Information (Detail) (USD $)

12 Months Ended

1 Months Ended

6 Months Ended

1 Months Ended

3 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2014

Jan. 31, 2014

Apr. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jan. 31, 2013

Mar. 31, 2013

Apr. 30, 2013

Dec. 31, 2013

Jan. 31, 2012

Sep. 30, 2012

Oct. 31, 2012

Mar. 31, 2014

acre

Dispositions [Abstract]

Cash proceeds from asset sales

$2,978,000,000

$4,458,000,000

$843,000,000

Goodwill included in the divested businesses' net book value

126,000,000

339,000,000

United Kingdom North Sea Cambo Asset [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

53,000,000

Gain (loss) on asset sale, pre-tax

33,000,000

Gain (loss) on asset sale, after-tax

33,000,000

Bayonne Energy Center LLC [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

79,000,000

Pangkah Asset [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

650,000,000

Gain (loss) on asset sale, pre-tax

31,000,000

Gain (loss) on asset sale, after-tax

-10,000,000

Goodwill included in the divested businesses' net book value

56,000,000

Thailand [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

805,000,000

Gain (loss) on asset sale, pre-tax

706,000,000

Gain (loss) on asset sale, after-tax

706,000,000

Goodwill included in the divested businesses' net book value

76,000,000

Utica Shale [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

1,075,000,000

Gain (loss) on asset sale, pre-tax

62,000,000

62,000,000

Gain (loss) on asset sale, after-tax

35,000,000

35,000,000

Area of land sold

77,000

Goodwill included in the divested businesses' net book value

11,000,000

Electric Generating Facility [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

320,000,000

Gain (loss) on asset sale, pre-tax

13,000,000

13,000,000

Gain (loss) on asset sale, after-tax

8,000,000

8,000,000

Beryl Fields And Scottish Area Gas Evacuation System Sage

Dispositions [Abstract]

Cash proceeds from asset sales

442,000,000

Gain (loss) on asset sale, pre-tax

328,000,000

Gain (loss) on asset sale, after-tax

323,000,000

Goodwill included in the divested businesses' net book value

48,000,000

Azeri-Chirag-Guneshli (ACG) Fields [Member]

Dispositions [Abstract]

Corporation's proportionate interest in oil and gas assets (in percentage)

3.00%

Baku-Tbilisi-Ceyhan (BTC) Pipeline [Member]

Dispositions [Abstract]

Corporation's proportionate interest in oil and gas assets (in percentage)

2.00%

Samara-Nafta [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

1,900,000,000

Gain (loss) on asset sale, pre-tax

1,119,000,000

Gain (loss) on asset sale, after-tax

1,119,000,000

Goodwill included in the divested businesses' net book value

148,000,000

Corporation's proportionate interest in oil and gas assets (in percentage)

90.00%

Cash proceeds from sale of subsidiary

2,100,000,000

Net gain on sale attributable to noncontrolling interest holder's share

168,000,000

Net gain on sale attributable to parent

951,000,000

Baku Tbilisi Ceyhan Pipeline And Azeri Chirag Guneshli Fields

Dispositions [Abstract]

Cash proceeds from asset sales

884,000,000

Gain (loss) on asset sale, pre-tax

360,000,000

Gain (loss) on asset sale, after-tax

360,000,000

Goodwill included in the divested businesses' net book value

52,000,000

Natuna A [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

656,000,000

Gain (loss) on asset sale, pre-tax

388,000,000

388,000,000

Gain (loss) on asset sale, after-tax

343,000,000

343,000,000

Goodwill included in the divested businesses' net book value

39,000,000

Snohvit [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

132,000,000

Gain (loss) on asset sale, pre-tax

36,000,000

Gain (loss) on asset sale, after-tax

36,000,000

Goodwill included in the divested businesses' net book value

14,000,000

Corporation's proportionate interest in oil and gas assets (in percentage)

3.00%

Schiehallion Field [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

524,000,000

Gain (loss) on asset sale, pre-tax

376,000,000

Gain (loss) on asset sale, after-tax

349,000,000

Goodwill included in the divested businesses' net book value

27,000,000

Corporation's proportionate interest in oil and gas assets (in percentage)

16.00%

Bittern Field [Member]

Dispositions [Abstract]

Cash proceeds from asset sales

187,000,000

Gain (loss) on asset sale, pre-tax

172,000,000

Gain (loss) on asset sale, after-tax

172,000,000

Goodwill included in the divested businesses' net book value

12,000,000

Corporation's proportionate interest in oil and gas assets (in percentage)

28.00%

Level 3 [Member] | Bayonne Energy Center LLC [Member]

Dispositions [Abstract]

Charge to reduce to fair value

84,000,000

Charge to reduce to fair value, after income taxes

$52,000,000

Exit_and_Disposal_Costs_Compon

Exit and Disposal Costs - Components of and Changes in Restructuring Accruals (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Restructuring Cost And Reserve [Line Items]
Balance at ending of period	$102
Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	171
Provision	76
Payments	-170
Balance at ending of period	77
Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	118
Provision	65
Payments	-158
Balance at ending of period	25
Continuing Operations [Member] | Exploration and Production [Member]
Restructuring Cost And Reserve [Line Items]
Balance at ending of period	16
Continuing Operations [Member] | Exploration and Production [Member] | Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	32
Provision	19
Payments	-35
Balance at ending of period	16
Continuing Operations [Member] | Exploration and Production [Member] | Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	53
Provision	-15
Payments	-38
Continuing Operations [Member] | Corporate, Interest and Other [Member]
Restructuring Cost And Reserve [Line Items]
Balance at ending of period	31
Continuing Operations [Member] | Corporate, Interest and Other [Member] | Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	26
Provision	16
Payments	-26
Balance at ending of period	16
Continuing Operations [Member] | Corporate, Interest and Other [Member] | Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	17
Provision	10
Payments	-12
Balance at ending of period	15
Discontinued Operations [Member]
Restructuring Cost And Reserve [Line Items]
Balance at ending of period	55
Discontinued Operations [Member] | Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	113
Provision	41
Payments	-109
Balance at ending of period	45
Discontinued Operations [Member] | Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Balance at beginning of period	48
Provision	70
Payments	-108
Balance at ending of period	$10

Exit_and_Disposal_Costs_Financ

Exit and Disposal Costs - Financial Statement Classification of Costs and Expenses Associated with Corporation's Restructuring Program (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Employee Severance	$76	$252
Employee Severance [Member] | Exploration Expenses, Including Dry Holes and Lease Impairment [Member]
Restructuring Cost And Reserve [Line Items]
Employee Severance	3	19
Employee Severance [Member] | Operating Costs and Expenses [Member]
Restructuring Cost And Reserve [Line Items]
Employee Severance	5	22
Employee Severance [Member] | General and Administrative Expenses [Member]
Restructuring Cost And Reserve [Line Items]
Employee Severance	27	63
Employee Severance [Member] | Income from discontinued operations [Member]
Restructuring Cost And Reserve [Line Items]
Employee Severance	41	148
Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs	65	220
Facility and Other Exit Costs [Member] | Operating Costs and Expenses [Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs		1
Facility and Other Exit Costs [Member] | General and Administrative Expenses [Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs	-2	54
Facility and Other Exit Costs [Member] | Income from discontinued operations [Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs	70	141
Facility and Other Exit Costs [Member] | Other Net [Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs		8
Facility and Other Exit Costs [Member] | Depreciation​ Depletion​ And​ Amortization​ Expenses​[Member]
Restructuring Cost And Reserve [Line Items]
Facility and Other Exit Costs	($3)	$16

Exit_and_Disposal_Costs_Additi

Exit and Disposal Costs - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Restructuring Cost And Reserve [Line Items]
Accrued restructuring costs	$102
Percentage of accrued employee severance to be paid in 2015	95.00%
Percentage of accrued facility and other exit costs to be paid in 2015	45.00%
Employee Severance [Member]
Restructuring Cost And Reserve [Line Items]
Accrued restructuring costs	77	171
Facility and Other Exit Costs [Member]
Restructuring Cost And Reserve [Line Items]
Accrued restructuring costs	$25	$118

Inventories_Inventories_Detail

Inventories - Inventories (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Inventory Disclosure [Abstract]
Crude oil	$246	$291
Natural gas and refined petroleum products		618
Less: LIFO adjustment		-339
Total net crude oil, natural gas and refined petroleum product inventories	246	570
Materials , supplies and merchandise	281	384
Total inventories	$527	$954

Inventories_Additional_Informa

Inventories - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Inventory [Line Items]
Percentage of LIFO inventories		43.00%
Inventories	$527	$954
Downstream Business [Member]
Inventory [Line Items]
Inventories		$355

Property_Plant_and_Equipment_C

Property, Plant and Equipment - Components of Property, Plant and Equipment (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Exploration and Production
Unproved properties	$1,468	$2,460
Proved properties	4,211	4,121
Wells, equipment and related facilities	40,649	37,274
Total Exploration and Production costs	46,328	43,855
Corporate, Interest and Other	194	2,095
Total — at cost	46,522	45,950
Less: Reserves for depreciation, depletion, amortization and lease impairment	19,005	17,179
Property, plant and equipment — net	$27,517	$28,771

Property_Plant_and_Equipment_C1

Property, Plant and Equipment - Components of Property, Plant and Equipment (Parenthetical) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Property, plant and equipment—net	$27,517	$28,771
Corporate, Interest and Other [Member] | Divested Retail Marketing Operations
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Property, plant and equipment—net		$1,021

Property_Plant_and_Equipment_A

Property, Plant and Equipment - Assets Held for Sale - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2012
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Goodwill allocated	1,869	$1,858	$2,208
Corporate, Interest and Other [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Assets held for sale, Other current assets		1,035
Assets held for sale, Accrued Liabilities		797
Exploration and Production [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Carrying amount of properties classified as held for sale	1,097
Goodwill allocated	76
Assets retirement obligations and deferred income taxes reported in Liabilities associated with assets held for sale	286
Pangkah [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Corporation's proportionate interest in oil and gas assets (in percentage)	75.00%

Property_Plant_and_Equipment_N

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Well	Well	Well
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$2,045	$2,259	$2,022
Additions to capitalized exploratory well costs pending the determination of proved reserves	292	237	407
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	-629	-106	-41
Capitalized exploratory well costs charged to expense	-235	-267	-129
Dispositions and other	-57	-78
Ending balance	$1,416	$2,045	$2,259
Number of wells at end of year	37	50	68

Property_Plant_and_Equipment_C2

Property, Plant and Equipment - Capitalized Exploratory Well Costs - Additional Information (Detail) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2014
				Well
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized exploratory well costs charged to expense	$235	$267	$129
Exploratory dry hole costs which were incurred and subsequently expensed	66	77	248
Capitalized exploratory well costs that have been capitalized for period greater than one year	1,232
Green Canyon 469 Block [Member]
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized exploratory well costs charged to expense	169
Area 54, Offshore Libya [Member]
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized exploratory well costs charged to expense		$260
Block WA-390-P, Offshore Western Australia [Member]
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized well costs	68.00%
Offshore Ghana [Member]
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized well costs	30.00%
Number of consecutive successful exploration wells	7
Number of wells appraisal drilling plans		7
Number of wells appraisal drilling plans approved	4
Number of wells appraisal drilling plans in process	3
Number of appraisal wells completed				3
Projects under planning and development [Member]
Capitalized Costs Of Unproved Properties Excluded From Amortization [Line Items]
Capitalized well costs	2.00%

Property_Plant_and_Equipment_E

Property, Plant and Equipment - Exploratory Drilling Costs Capitalized (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$1,232
Year 2013 [Member]
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	74
Year 2012 [Member]
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	373
Year 2011 [Member]
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	338
Year 2010 [Member]
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	211
2009 and prior [Member]
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$236

Goodwill_Changes_in_Carrying_A

Goodwill - Changes in Carrying Amount of Goodwill (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]
Beginning balance at January 1	$1,869	$2,208
Acquisitions	115
Dispositions	-126	-339
Ending balance at December 31	$1,858	$1,869

Goodwill_Changes_in_Carrying_A1

Goodwill - Changes in Carrying Amount of Goodwill (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]
Disposal of goodwill, other assets sold	$21
Goodwill Reclassified to Assets Held for Sale	$76

Asset_Impairments_Additional_I

Asset Impairments - Additional Information (Detail) (USD $)	12 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Significant Acquisitions And Disposals [Line Items]
Sale of assets	$2,978	$4,458	$843
Impairment charge before income tax		289	582
Natuna A [Member]
Significant Acquisitions And Disposals [Line Items]
Sale of assets				656
Gain on sale, pre-tax		388		388
Gain on sale, after-tax		343		343
Exploration and Production [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment charge before income tax			582
Impairment charge after income tax			344
Exploration and Production [Member] | Cotulla Area of Eagle Ford Shale [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment charge before income tax			374
Impairment charge after income tax			228
Exploration and Production [Member] | Corporation's Non-producing Properties UK North Sea [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment charge before income tax			208
Impairment charge after income tax			116
Exploration and Production [Member] | Natuna A And Pangkah [Member]
Significant Acquisitions And Disposals [Line Items]
Sale of assets		1,300
Exploration and Production [Member] | Natuna A [Member]
Significant Acquisitions And Disposals [Line Items]
Gain on sale, pre-tax		388		388
Gain on sale, after-tax		343		343
Exploration and Production [Member] | Pangkah [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment charge before income tax		289
Impairment charge after income tax		$187

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes to Corporation's Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$2,772	$2,661
Liabilities incurred	63	42
Liabilities settled or disposed of	-420	-576
Accretion expense	136	129
Revisions of estimated liabilities	263	573
Foreign currency translation	-91	-57
Asset retirement obligations at end of period	2,723	2,772
Less: Current obligations	442	523
Long-term obligations at end of period	$2,281	$2,249

Debt_and_Interest_Expense_Long

Debt and Interest Expense - Long-Term Debt (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]
Fixed-rate public notes	$5,625	$5,275
Financing obligations associated with floating production system	331	296
Other fixed-rate notes, weighted average rate 12.9%		135
Project lease financing, weighted average rate 5.1%		60
Fair value adjustments - interest rate hedging	31	30
Other debt		2
Total debt	5,987	5,798
Less: Short-term debt and current maturities of long-term debt	68	378
Total long-term debt	5,919	5,420
7.0% Due 2014 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes		250
1.3% Due 2017 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	300
8.1% Due 2019 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	999	998
3.5% Due 2024 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	298
7.9% Due 2029 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	696	695
7.3% Due 2031 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	747	747
7.1% Due 2033 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	598	598
6.0% Due 2040 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	745	745
5.6% Due 2041 [Member]
Debt Instrument [Line Items]
Fixed-rate public notes	$1,242	$1,242

Debt_and_Interest_Expense_Long1

Debt and Interest Expense - Long-Term Debt (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014
Debt Instrument [Line Items]
Weighted average interest rate	6.40%
Other Fixed Rate Notes 12.9% [Member]
Debt Instrument [Line Items]
Weighted average interest rate	12.90%
Project Lease Financing 5.1% [Member]
Debt Instrument [Line Items]
Weighted average interest rate	5.10%
7.0% Due 2014 [Member]
Debt Instrument [Line Items]
Coupon rate	7.00%
Maturity year	2014
1.3% Due 2017 [Member]
Debt Instrument [Line Items]
Coupon rate	1.30%
Maturity year	2017
8.1% Due 2019 [Member]
Debt Instrument [Line Items]
Coupon rate	8.10%
Maturity year	2019
3.5% Due 2024 [Member]
Debt Instrument [Line Items]
Coupon rate	3.50%
Maturity year	2024
7.9% Due 2029 [Member]
Debt Instrument [Line Items]
Coupon rate	7.90%
Maturity year	2029
7.3% Due 2031 [Member]
Debt Instrument [Line Items]
Coupon rate	7.30%
Maturity year	2031
7.1% Due 2033 [Member]
Debt Instrument [Line Items]
Coupon rate	7.10%
Maturity year	2033
6.0% Due 2040 [Member]
Debt Instrument [Line Items]
Coupon rate	6.00%
Maturity year	2040
5.6% Due 2041 [Member]
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2041

Debt_and_Interest_Expense_Addi

Debt and Interest Expense - Additional Information (Detail) (USD $)	12 Months Ended			0 Months Ended	1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2015	Jan. 31, 2015	Jun. 30, 2014
		Lease
Debt Instrument [Line Items]
New syndicated revolving credit facility maturing in April 2016	$4,000,000,000
Interest rate on the borrowings on the credit facility description	1.25% above the London Interbank Offered Rate.
Credit facility fee (per annum)	0.25%
Maturity of revolving credit facilities	2016-04
Unsecured fixed-rate notes						600,000,000
Unsecured fixed-rate notes issued, net of discount						598,000,000
Repayments of debt	590,000,000
Retirement of various lease obligations	249,000,000
Repayments under available credit facilities		2,348,000,000
Capital lease obligations		98,000,000
Acquisition of leased Hess retail gasoline stations		50
Total other debt repayments		136,000,000
Fixed-rate notes, principal amount	5,650,000,000
Fixed-rate notes, principal amount net of unamortized discount	5,625,000,000	5,275,000,000
Weighted average interest rate	6.40%
Aggregate long-term debt, maturing in 2015	68,000,000
Aggregate long-term debt, maturing in 2016	71,000,000
Aggregate long-term debt, maturing in 2017	373,000,000
Aggregate long-term debt, maturing in 2018	78,000,000
Aggregate long-term debt, maturing in 2019	1,070,000,000
Additional secured debt allowed to be borrowed	5,600,000,000
Outstanding letters of credit	397,000,000	410,000,000
Letters of credit outstanding, contingent liabilities	54,000,000
Letters of credit outstanding, balance sheet liabilities	343,000,000
Interest paid, net of amounts capitalized	326,000,000	408,000,000	419,000,000
Capitalized interest	76,000,000	60,000,000	28,000,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Repayments under available credit facilities		758,000,000
Short-term Credit Facilities [Member]
Debt Instrument [Line Items]
Repayments under available credit facilities		990,000,000
Asset-Backed Credit Facility [Member]
Debt Instrument [Line Items]
Repayments under available credit facilities		600,000,000
WilcoHess [Member]
Debt Instrument [Line Items]
Repayments of debt	74,000,000
Leased Floating Production System [Member]
Debt Instrument [Line Items]
Additional non-cash debt	68,000,000	116,000,000
1.3% Due 2017 [Member]
Debt Instrument [Line Items]
Unsecured fixed-rate notes						300,000,000
Debt notes maturity period	30-Jun-17
Fixed-rate notes, principal amount net of unamortized discount	300,000,000
3.5% Due 2024 [Member]
Debt Instrument [Line Items]
Unsecured fixed-rate notes						300,000,000
Debt notes maturity period	31-Jul-24
Fixed-rate notes, principal amount net of unamortized discount	298,000,000
Unsecured Fixed-Rate Notes [Member]
Debt Instrument [Line Items]
Repayments of debt	$250,000,000
Subsequent Event
Debt Instrument [Line Items]
Interest rate on the borrowings on the credit facility description					1.075% above the London Interbank Offered Rate
Credit facility fee (per annum)					0.18%
Maturity of revolving credit facilities					2020-01
Credit agreement term				5 years

Debt_and_Interest_Expense_Outs

Debt and Interest Expense - Outstanding Letters of Credit (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Disclosure [Abstract]
Committed lines	$25	$274
Uncommitted lines	372	136
Total	$397	$410

Debt_and_Interest_Expense_Outs1

Debt and Interest Expense - Outstanding Letters of Credit (Parenthetical) (Detail) (Committed and Uncommitted Lines [Member])	12 Months Ended
	Dec. 31, 2014
Committed and Uncommitted Lines [Member]
Line Of Credit Facility [Line Items]
Maturity year	2016

Sharebased_Compensation_Additi

Share-based Compensation - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period for stock options from the date of grant	3 years
Vesting period for outstanding restricted common stock from the date of grant	3 years
Option term (in years)	10 years
Performance of predetermined peer companies	3 years
Minimum PSU awards payout	0.00%
Maximum PSU awards payout	200.00%
Reversed share-based compensation expense related to grants that are expected to be forfeited		$33
Unearned compensation expense, before income taxes due 2015	66
Unearned compensation expense, before income taxes due 2016	39
Unearned compensation expense, before income taxes due 2017	7
Long-term Incentive Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Available for future awards of restricted stock, stock options and PSUs	8.5
Common stock authorized for issuance	29
Restricted Stock [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Reversed share-based compensation expense related to grants that are expected to be forfeited		25
Performance Share Units [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Reversed share-based compensation expense related to grants that are expected to be forfeited		7
Stock Options [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Reversed share-based compensation expense related to grants that are expected to be forfeited		$1

Sharebased_Compensation_Shareb

Share-based Compensation - Share-based Compensation Expense (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Restricted stock, After Income Taxes	$39	$19	$35
Stock options, After Income Taxes	1	8	21
Performance share units , After Income Taxes	12	6	5
Total, After Income Taxes	52	33	61
Restricted stock, Before Income Taxes	62	31	57
Stock options, Before Income Taxes	2	13	34
Performance share units, Before Income Taxes	19	10	8
Total, Before Income Taxes	$83	$54	$99

Sharebased_Compensation_Shareb1

Share-based Compensation - Share-based Compensation Expense (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share Based Compensation Expense Per Share [Line Items]
Pre-tax share-based compensation expense (benefit) included in Income from Continuing operations	$83	$54	$99
Income From Continuing Operations [Member]
Share Based Compensation Expense Per Share [Line Items]
Pre-tax share-based compensation expense (benefit) included in Income from Continuing operations	$87	$60	$83

Sharebased_Compensation_Summar

Share-based Compensation - Summary of Stock-based Compensation Activity (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Exercised, Options	-3,300	-2,300	-200
Restricted Stock [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Weighted Average Fair Value, Beginning	69.36
Granted, Weighted Average Fair Value	81.2
Vested, Weighted Average Fair Value	82.42
Forfeited, Weighted Average Fair Value	68.74
Outstanding, Weighted Average Fair Value, Ending balance	71.58
Outstanding Stock, Beginning balance	2,865
Granted Stock	1,081
Vested Stock	-510
Forfeited Stock	-535
Outstanding Stock, Ending balance	2,901
Stock Options [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Weighted Average Exercise Price per share, Beginning balance	63.08
Granted, Weighted Average Exercise Price per share	80.35
Exercised, Weighted Average Exercise Price per Share	54.99
Forfeited, Weighted Average Exercise Price per Share	85.07
Outstanding, Weighted Average Exercise Price per Share, Ending balance	66.79
Outstanding, Options, Beginning balance	10,141
Granted, Options	163
Exercised, Options	-3,327
Forfeited, Options	-211
Outstanding, Options, Ending balance	6,766
Performance Share Units [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Weighted Average Fair Value, Beginning	89.45
Granted, Weighted Average Fair Value	90.32
Forfeited, Weighted Average Fair Value	88.6
Outstanding, Weighted Average Fair Value, Ending balance	89.91
Outstanding Stock, Beginning balance	635
Granted Stock	298
Forfeited Stock	-133
Outstanding Stock, Ending balance	800

Sharebased_Compensation_Summar1

Share-based Compensation - Summary of Information Regarding Outstanding and Exercisable Stock Options (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Options Outstanding	6,766
Outstanding Options, Weighted-Average Remaining Contractual Life	4 years
Outstanding Options, Weighted-Average Exercise Price per Share	$66.79
Options Exercisable	6,594
Options Exercisable, Weighted-Average Exercise Price per Share	$66.47
Exercise Price Range 20.00-40.00 [Member]
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Range of Exercise Prices, lower limit	$20
Range of Exercise Prices, upper limit	$40
Options Outstanding	65
Outstanding Options, Weighted-Average Remaining Contractual Life	1 year
Outstanding Options, Weighted-Average Exercise Price per Share	$29.96
Options Exercisable	65
Options Exercisable, Weighted-Average Exercise Price per Share	$29.96
Exercise Price Range 40.01-50.00 [Member]
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Range of Exercise Prices, lower limit	$40.01
Range of Exercise Prices, upper limit	$50
Options Outstanding	684
Outstanding Options, Weighted-Average Remaining Contractual Life	2 years
Outstanding Options, Weighted-Average Exercise Price per Share	$49.42
Options Exercisable	681
Options Exercisable, Weighted-Average Exercise Price per Share	$49.44
Exercise Price Range 50.01-60.00 [Member]
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Range of Exercise Prices, lower limit	$50.01
Range of Exercise Prices, upper limit	$60
Options Outstanding	1,927
Outstanding Options, Weighted-Average Remaining Contractual Life	4 years
Outstanding Options, Weighted-Average Exercise Price per Share	$55.08
Options Exercisable	1,921
Options Exercisable, Weighted-Average Exercise Price per Share	$55.08
Exercise Price Range 60.01-80.00 [Member]
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Range of Exercise Prices, lower limit	$60.01
Range of Exercise Prices, upper limit	$80
Options Outstanding	1,302
Outstanding Options, Weighted-Average Remaining Contractual Life	4 years
Outstanding Options, Weighted-Average Exercise Price per Share	$60.68
Options Exercisable	1,302
Options Exercisable, Weighted-Average Exercise Price per Share	$60.68
Exercise Price Range 80.01-120.00 [Member]
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Range of Exercise Prices, lower limit	$80.01
Range of Exercise Prices, upper limit	$120
Options Outstanding	2,788
Outstanding Options, Weighted-Average Remaining Contractual Life	5 years
Outstanding Options, Weighted-Average Exercise Price per Share	$82.85
Options Exercisable	2,625
Options Exercisable, Weighted-Average Exercise Price per Share	$83

Sharebased_Compensation_Weight

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards (Detail) (Performance Share Units [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	0.65%	0.36%
Stock price volatility	35.90%	35.90%
Contractual term in years	3 years	3 years
Hess Corporation [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Grant date price of Hess common stock	80.35	69.49

Foreign_Currency_Additional_In

Foreign Currency - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Foreign Currency [Abstract]
Pre-tax foreign currency gains (losses)	($43)	($54)	$36
Increase (decrease) in stockholders' equity as a result of foreign currency	($757)	($1)

Retirement_Plans_Additional_In

Retirement Plans - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Age of qualified retirees, minimum	55 years
Age of qualified retirees, maximum	65 years
Estimated pension and postretirement medical expense for 2015	$80
Estimated amortization of unrecognized net actuarial losses for 2015	75
Net asset value per fund share related to short-term investment funds	$1
Budgeted contributions to funded pension plans in 2015	55
Expense related to contribution for several defined contribution plans	32	41	40
Equity securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets	50.00%
Fixed income securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets	25.00%
Other types of investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets	25.00%
Funded Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation for the defined benefit pension plans	2,325	1,873
Unfunded Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation for the defined benefit pension plans	$214	$222

Retirement_Plans_Funded_Status

Retirement Plans - Funded Status of Pension and Postretirement Medical Plans (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Change in benefit obligation
Actuarial (gain) loss	$125
Change in fair value of plan assets
Beginning balance	2,145
Ending balance	2,251
Funded Pension Plans [Member]
Change in benefit obligation
Beginning balance	1,957	2,110
Service cost	45	61
Interest cost	91	82
Actuarial (gain) loss	470	-139
Benefit payments	-77	-69
Plan curtailments	-3	-103
Special termination benefits	2	5
Foreign currency exchange rate changes	-35	10
Ending balance	2,450	1,957
Change in fair value of plan assets
Beginning balance	2,145	1,763
Actual return on plan assets	151	292
Employer contributions	68	146
Benefit payments	-77	-69
Foreign currency exchange rate changes	-36	13
Ending balance	2,251	2,145
Funded status (plan assets greater (less) than benefit obligations) at December 31	-199	188
Unrecognized net actuarial (gains) losses	859	405
Unfunded Pension Plan [Member]
Change in benefit obligation
Beginning balance	253	234
Service cost	12	12
Interest cost	9	7
Actuarial (gain) loss	61	28
Benefit payments	-57	-20
Plan curtailments		-8
Ending balance	278	253
Change in fair value of plan assets
Employer contributions	56	20
Benefit payments	-56	-20
Funded status (plan assets greater (less) than benefit obligations) at December 31	-278	-253
Unrecognized net actuarial (gains) losses	135	108
Postretirement Medical Plan [Member]
Change in benefit obligation
Beginning balance	97	134
Service cost	4	4	7
Interest cost	3	3	5
Actuarial (gain) loss	-4	-4
Benefit payments	-6	-5
Plan curtailments		-35
Ending balance	94	97	134
Change in fair value of plan assets
Employer contributions	6	5
Benefit payments	-6	-5
Funded status (plan assets greater (less) than benefit obligations) at December 31	-94	-97
Unrecognized net actuarial (gains) losses	($5)	($2)

Retirement_Plans_Funded_Status1

Retirement Plans - Funded Status of Pension and Postretirement Medical Plans (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Compensation And Retirement Disclosure [Abstract]
Settlement Payments	$55
Defined benefit plan change in discount rate actuarial (gain) loss	330
Defined benefit plan change in mortality assumptions actuarial (gain) loss	$125

Retirement_Plans_Amounts_Recog

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Funded Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	($199)	$188
Accumulated other comprehensive loss, pre-tax	859	405
Unfunded Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	-278	-253
Accumulated other comprehensive loss, pre-tax	135	108
Postretirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	-94	-97
Accumulated other comprehensive loss, pre-tax	($5)	($2)

Retirement_Plans_Amounts_Recog1

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Parenthetical) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Compensation And Retirement Disclosure [Abstract]
After-tax deficit reflected in Accumulated other comprehensive income (loss)	$652	$342

Retirement_Plans_Components_of

Retirement Plans - Components of Net Periodic Benefit Cost (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Settlement Payments	($55)
Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	57	73	74
Interest cost	100	89	88
Expected return on plan assets	-161	-141	-116
Amortization of unrecognized net actuarial losses	31	61	83
Settlement Payments	24		9
Curtailment loss		1
Special termination benefit recognized	1	5
Net periodic benefit cost	52	88	138
Postretirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	7
Interest cost	3	3	5
Amortization of unrecognized net actuarial losses		1	2
Net periodic benefit cost	$7	$8	$14

Retirement_Plans_Weighted_Aver

Retirement Plans - Weighted Average Actuarial Assumptions Used in Calculation of Pension Plans (Detail) (Funded and unfunded pension plans [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Funded and unfunded pension plans [Member]
Weighted average assumptions used to determine benefit obligations at December 31
Discount rate	3.80%	4.60%	3.80%
Rate of compensation increase	5.00%	4.40%	4.30%
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31
Discount rate	4.60%	4.00%	4.30%
Expected return on plan assets	7.50%	7.50%	7.50%
Rate of compensation increase	4.40%	4.30%	4.30%

Retirement_Plans_Actuarial_Ass

Retirement Plans - Actuarial Assumptions Used by Corporation's Postretirement Medical Plan (Detail) (Postretirement Medical Plan [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Postretirement Medical Plan [Member]
Assumptions used to determine benefit obligations at December 31
Discount rate	3.10%	3.60%	3.10%
Initial health care trend rate	6.80%	7.10%	7.30%
Ultimate trend rate	4.50%	4.60%	4.80%
Year in which ultimate trend rate is reached	2029	2027	2022

Retirement_Plans_Fair_Value_of

Retirement Plans - Fair Value of Plan's Financial Assets (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	$2,251	$2,145
Cash and Short-term Investment Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	53	75
U.S. Equities (domestic) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	719	729
International Equities (non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	249	252
Global Equities (domestic and non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	228	216
Treasury and Government Issued [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	222	170
Government Related [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	8	9
Mortgage-backed Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	148	110
Corporate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	140	127
Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	302	291
Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	105	89
Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	60	57
Diversified Commodities Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	17	20
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	822	833
Level 1 [Member] | Cash and Short-term Investment Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	6	3
Level 1 [Member] | U.S. Equities (domestic) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	719	729
Level 1 [Member] | International Equities (non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	72	81
Level 1 [Member] | Global Equities (domestic and non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	10	8
Level 1 [Member] | Corporate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	3	2
Level 1 [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	12	10
Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	972	882
Level 2 [Member] | Cash and Short-term Investment Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	47	72
Level 2 [Member] | International Equities (non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	177	171
Level 2 [Member] | Global Equities (domestic and non-U.S.) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	218	208
Level 2 [Member] | Treasury and Government Issued [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	222	169
Level 2 [Member] | Government Related [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	7	9
Level 2 [Member] | Mortgage-backed Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	147	109
Level 2 [Member] | Corporate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	137	124
Level 2 [Member] | Diversified Commodities Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	17	20
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	457	430	377
Level 3 [Member] | Treasury and Government Issued [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets		1
Level 3 [Member] | Government Related [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	1
Level 3 [Member] | Mortgage-backed Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	1	1
Level 3 [Member] | Corporate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets		1
Level 3 [Member] | Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	302	291	255
Level 3 [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	105	89	75
Level 3 [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of the plan's financial assets	$48	$47	$45

Retirement_Plans_Fair_Value_Ba

Retirement Plans - Fair Value Based on Level 3 Inputs Held by Institutional Funds (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Ending balance	$2,251	$2,145
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	430	377
Actual return on plan assets	24	39
Purchases, sales or other settlements	3	14
Ending balance	457	430
Fixed Income [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	3	2
Purchases, sales or other settlements	-1	1
Ending balance	2	3
Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Ending balance	302	291
Hedge Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	291	255
Actual return on plan assets	9	26
Purchases, sales or other settlements	2	10
Ending balance	302	291
Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Ending balance	105	89
Private Equity Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	89	75
Actual return on plan assets	15	11
Purchases, sales or other settlements	1	3
Ending balance	105	89
Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Ending balance	60	57
Real Estate Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	47	45
Actual return on plan assets		2
Purchases, sales or other settlements	1
Ending balance	$48	$47

Retirement_Plans_Estimated_Fut

Retirement Plans - Estimated Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Compensation And Retirement Disclosure [Abstract]
2015	$157
2016	112
2017	118
2018	121
2019	129
Years 2020 to 2024	$694

Income_Taxes_Provision_Benefit

Income Taxes - Provision (Benefit) for Income Taxes from Continuing Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Expense Benefit Continuing Operations [Line Items]
United States Federal, Current	($1)	$8	$30
United States Federal, Deferred	156	103	-435
Foreign, Current	453	941	2,012
Foreign, Deferred	79	186	-224
Total Foreign Income Tax provision	532	1,127	1,788
Total provision before adjustment	744	1,247	1,414
Adjustment of deferred taxes for foreign income tax law changes		-682	115
Provision (benefit) for income taxes	744	565	1,529
State [Member]
Income Tax Expense Benefit Continuing Operations [Line Items]
Provision (benefit) for income taxes	57	9	31
Federal and State [Member]
Income Tax Expense Benefit Continuing Operations [Line Items]
Provision (benefit) for income taxes	$212	$120	($374)

Income_Taxes_Provision_Benefit1

Income Taxes - Provision (Benefit) for Income Taxes from Continuing Operations (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Denmark [Member]
Income Tax Expense Benefit Continuing Operations [Line Items]
Effect of hydrocarbon income tax law change	$674
Norway [Member]
Income Tax Expense Benefit Continuing Operations [Line Items]
Effect of change in hydrocarbon and base corporate income tax rates	$8

Income_Taxes_Income_From_Conti

Income Taxes - Income From Continuing Operations Before Income Taxes (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
United States	$676	$580	($608)
Foreign	1,760	4,021	3,945
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	$2,436	$4,601	$3,337

Income_Taxes_Components_of_Def

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Deferred tax liabilities
Property, plant and equipment and investments	($5,361)	($5,581)
Other	-269	-155
Total deferred tax liabilities	-5,630	-5,736
Deferred tax assets
Net operating loss carryforwards	3,010	2,726
Tax credit carryforwards	193	161
Property, plant and equipment and investments	2,245	2,643
Accrued compensation, deferred credits and other liabilities	449	982
Asset retirement obligations	1,421	1,516
Other	261	216
Total deferred tax assets	7,579	8,244
Valuation allowances	-1,416	-1,519
Total deferred tax assets, net of valuation allowances	6,163	6,725
Net deferred tax assets	$533	$989

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Examination [Line Items]
Gross deferred assets	$3,010,000,000
Alternative minimum tax credit carryforwards	109,000,000
Other business credit carryforwards	1,000,000
Foreign tax credit carryforwards	83,000,000
Year in which foreign tax credit carryforwards begin to expire	2016
DEFERRED INCOME TAXES	2,169,000,000	2,319,000,000
Net deferred tax liability	2,009,000,000	2,292,000,000
Unrecognized tax benefits that would impact effective income tax rate	528,000,000
Number of months impacting effective income tax rate if unrecognized tax benefits are recognized	12 months
The low end of the range of potential unrecognized tax benefits reasonably possible to be reduced by settlements or lapses of statutes of limitation		1,000,000
Accrued interest and penalties	62,000,000	52,000,000
Undistributed earnings from foreign subsidiaries expected to be indefinitely reinvested in foreign operations	8,300,000,000
Income taxes paid (net of refunds)	455,000,000	1,353,000,000	1,822,000,000
Minimum [Member]
Income Tax Examination [Line Items]
The low end of the range of potential unrecognized tax benefits reasonably possible to be reduced by settlements or lapses of statutes of limitation	94,000,000
Assets Held for Sale [Member] | HETCO [Member]
Income Tax Examination [Line Items]
DEFERRED INCOME TAXES	5,000,000
Assets Held for Sale [Member] | Thailand and Indonesia Subsidiaries [Member]
Income Tax Examination [Line Items]
Net deferred tax liability		157,000,000
Foreign Jurisdictions [Member]
Income Tax Examination [Line Items]
Gross deferred assets	2,131,000,000
Year in which operating losses begin to expire	2029
Gross deferred assets net of valuation allowance	1,504,000,000
U.S. Federal [Member]
Income Tax Examination [Line Items]
Gross deferred assets	712,000,000
Year in which operating losses begin to expire	2020
State [Member]
Income Tax Examination [Line Items]
Gross deferred assets	$167,000,000
Year in which operating losses begin to expire	2015

Income_Taxes_Deferred_Tax_Asse

Income Taxes - Deferred Tax Assets and Liabilities, Net (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Income Tax Disclosure [Abstract]
Other current assets	$373	$963
Deferred income taxes (long-term asset)	2,169	2,319
Accrued liabilities		-1
Deferred income taxes (long-term liability)	-2,009	-2,292
Net deferred tax assets	$533	$989

Income_Taxes_Difference_Betwee

Income Taxes - Difference Between Corporation's Effective Income Tax Rate from Continuing Operations and U.S. Statutory Rate (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
U.S. statutory rate	35.00%	35.00%	35.00%
Effect of foreign operations	1.00%	6.90%	12.50%
State income taxes, net of Federal income tax	1.50%	0.10%	0.60%
Change in enacted tax laws		-14.80%	3.40%
Gains on asset sales, net	-8.30%	-15.60%	-5.40%
Other	1.30%	0.70%	-0.30%
Total	30.50%	12.30%	45.80%

Income_Taxes_Reconciliation_of

Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Balance at January 1	$570	$523
Additions based on tax positions taken in the current year	42	161
Additions based on tax positions of prior years	70	2
Reductions based on tax positions of prior years	-76	-96
Reductions due to settlements with taxing authorities	-3	-19
Reductions due to lapses in statutes of limitation		-1
Balance at December 31	$603	$570

Outstanding_and_Weighted_Avera2

Outstanding and Weighted Average Common Shares - Changes in Corporation's Outstanding Common Shares (Detail)	5 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Balance at January 1		325,314,177	341.5	340
Activity related to restricted common stock awards, net		600,000	800,000	1,300,000
Stock options exercised		3,300,000	2,300,000	200,000
Shares repurchased	-19,300,000	-43,400,000	-19,300,000
Balance at December 31	325,314,177	285,834,964	325,314,177	341.5

Outstanding_and_Weighted_Avera3

Outstanding and Weighted Average Common Shares - Basic and Diluted Earnings Per Share (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Income from continuing operations, net of income taxes	$1,692	$4,036	$1,808
Less: Net income attributable to noncontrolling interests		176	18
Net income from continuing operations attributable to Hess Corporation	1,692	3,860	1,790
Income (loss) from discontinued operations, net of income taxes	682	1,186	255
Less: Net income (loss) attributable to noncontrolling interests	57	-6	20
Income from discontinued operations, net of income taxes	625	1,192	235
NET INCOME ATTRIBUTABLE TO HESS CORPORATION	$2,317	$5,052	$2,025
Weighted average common shares outstanding:
Basic	303.7	336.6	338.4
Effect of dilutive securities
Restricted common stock	1.5	1.4	1.1
Stock options	1.8	1.7	0.8
Performance share units	0.7	1.2
Diluted	307.7	340.9	340.3
Basic:
Continuing operations	$5.57	$11.47	$5.29
Discontinued operations	$2.06	$3.54	$0.69
NET INCOME PER SHARE	$7.63	$15.01	$5.98
Diluted:
Continuing operations	$5.50	$11.33	$5.26
Discontinued operations	$2.03	$3.49	$0.69
NET INCOME PER SHARE	$7.53	$14.82	$5.95

Outstanding_and_Weighted_Avera4

Outstanding and Weighted Average Common Shares - Additional Information (Detail) (USD $)	3 Months Ended												12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Out-of-the-money stock options													1,400,000	4,400,000	9,200,000
Cash dividends on common stock	$0.25	$0.25	$0.25	$0.25	$0.25	$0.25	$0.10	$0.10	$0.10	$0.10	$0.10	$0.10	$1	$0.70	$0.40
Performance Share Units [Member]
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Out-of-the-money stock options															414,175

Share_Repurchase_Plan_Addition

Share Repurchase Plan - Additional Information (Detail) (USD $)	5 Months Ended	12 Months Ended
Share data in Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	31-May-14	Mar. 31, 2013
Equity [Abstract]
Repurchase of outstanding common stock				$6,500,000,000	$4,000,000,000
Number of shares purchased	19.3	43.4	19.3
Shares purchased value	1,500,000,000	3,722,000,000	1,538,000,000
Average cost per share of share repurchased	$79.65	$85.83
Additional amount of common stock that may be repurchased under this board authorized plan		$1,240,000,000

Leased_Assets_Future_Minimum_R

Leased Assets - Future Minimum Rental Payments (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Leases [Abstract]
2015	$773
2016	627
2017	422
2018	348
2019	303
Remaining years	345
Total minimum lease payments	2,818
Less: Income from subleases	36
Net minimum lease payments	$2,782

Leased_Assets_Rental_Expense_D

Leased Assets - Rental Expense (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Leases [Abstract]
Total rental expense	$248	$355	$375
Less: Income from subleases	17	15	15
Net rental expense	$231	$340	$360

Guarantees_and_Contingencies_A

Guarantees and Contingencies - Additional Information (Detail) (USD $)	1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2014
Loss Contingencies [Line Items]
Contingent liability associated with letters of credit		$54
Settlements amount paid by HOVENSA		3.5
Litigation settlement for MTBE	35
VIRGIN ISLANDS, US
Loss Contingencies [Line Items]
Agreement to pay government of the U.S. Virgin Islands		$40

Segment_Information_Additional

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014
	Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	1

Segment_Information_Financial_

Segment Information - Financial Data by Operating Segment for Continuing Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$10,737	$11,905	$12,245
Net income (loss) from continuing operations attributable to Hess Corporation	1,692	3,860	1,790
Interest expense	323	406	419
Depreciation, depletion and amortization	3,224	2,687	2,866
Asset impairments		289	582
Provision (benefit) for income taxes	744	565	1,529
Investments in affiliates	151	506	273
Identifiable assets	37,420	39,215	38,500
Capital expenditures	5,274	5,767	7,682
Exploration and Production [Member]
Segment Reporting Information [Line Items]
Asset impairments			582
Corporate, Interest and Other [Member]
Segment Reporting Information [Line Items]
Net income (loss) from continuing operations attributable to Hess Corporation	-406	-443	-422
Depreciation, depletion and amortization	14	16	13
Provision (benefit) for income taxes	-252	-266	-264
Identifiable assets	908	1,352	813
Capital expenditures	53	58	6
Continuing Operations [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,737	11,905	12,245
Net income (loss) from continuing operations attributable to Hess Corporation	2,098	4,303	2,212
Depreciation, depletion and amortization	3,210	2,671	2,853
Asset impairments		289	582
Provision (benefit) for income taxes	996	831	1,793
Investments in affiliates	151	109	75
Identifiable assets	36,512	37,863	37,687
Capital expenditures	5,221	5,709	7,676
Continuing Operations [Member] | Corporate, Interest and Other [Member]
Segment Reporting Information [Line Items]
Net income (loss) from continuing operations attributable to Hess Corporation	-406	-443	-422
Interest expense	323	406	419
Depreciation, depletion and amortization	14	16	13
Provision (benefit) for income taxes	-252	-266	-264
Investments in affiliates		397	198
Identifiable assets	908	1,352	813
Capital expenditures	$53	$58	$6

Segment_Information_Financial_1

Segment Information - Financial Information by Major Geographic Area (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$10,737	$11,905	$12,245
Net income (loss) from continuing operations attributable to Hess Corporation	1,692	3,860	1,790
Depreciation, depletion and amortization	3,224	2,687	2,866
Asset impairments		289	582
Provision (benefit) for income taxes	744	565	1,529
Identifiable assets	37,420	39,215	38,500
Property, plant and equipment (net)	27,517	27,750	27,542
Capital expenditures	5,274	5,767	7,682
Corporate, Interest and Other [Member]
Segment Reporting Information [Line Items]
Net income (loss) from continuing operations attributable to Hess Corporation	-406	-443	-422
Depreciation, depletion and amortization	14	16	13
Provision (benefit) for income taxes	-252	-266	-264
Identifiable assets	908	1,352	813
Property, plant and equipment (net)	116	193	86
Capital expenditures	53	58	6
United States [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,270	6,076	5,294
Net income (loss) from continuing operations attributable to Hess Corporation	656	777	438
Depreciation, depletion and amortization	1,751	1,393	1,406
Asset impairments			432
Provision (benefit) for income taxes	446	495	267
Identifiable assets	18,472	18,617	16,403
Property, plant and equipment (net)	15,595	14,873	12,893
Capital expenditures	3,467	3,613	4,620
Europe [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,557	1,337	2,530
Net income (loss) from continuing operations attributable to Hess Corporation	226	2,051	1,010
Depreciation, depletion and amortization	683	484	466
Asset impairments			119
Provision (benefit) for income taxes	91	-646	376
Identifiable assets	7,800	9,032	8,957
Property, plant and equipment (net)	6,339	7,475	8,172
Capital expenditures	524	689	1,330
Africa [Member]
Segment Reporting Information [Line Items]
Operating revenues	2,002	2,736	2,484
Net income (loss) from continuing operations attributable to Hess Corporation	545	594	602
Depreciation, depletion and amortization	487	518	529
Provision (benefit) for income taxes	435	767	905
Identifiable assets	3,049	3,198	3,811
Property, plant and equipment (net)	2,235	2,310	2,516
Capital expenditures	399	578	733
Asia and Other Countries [Member]
Segment Reporting Information [Line Items]
Operating revenues	908	1,756	1,937
Net income (loss) from continuing operations attributable to Hess Corporation	671	881	162
Depreciation, depletion and amortization	289	276	452
Asset impairments		289	31
Provision (benefit) for income taxes	24	215	245
Identifiable assets	7,191	7,016	8,516
Property, plant and equipment (net)	3,232	2,899	3,875
Capital expenditures	$831	$829	$993

Segment_Information_Financial_2

Segment Information - Financial Information by Major Geographic Area (Parenthetical) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Segment Reporting Information [Line Items]
Property, plant and equipment—net	$27,517	$28,771
Norway [Member]
Segment Reporting Information [Line Items]
Property, plant and equipment—net	$5,246	$6,348	$6,426

Related_Party_Transactions_Rel

Related Party Transactions - Related Party Transactions (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
HOVENSA [Member]
Related Party Transaction [Line Items]
Purchases			$145
Sales	31	90	191
Bayonne Energy Center LLC [Member]
Related Party Transaction [Line Items]
Purchases		38	20
WilcoHess [Member]
Related Party Transaction [Line Items]
Sales	$211	$2,828	$3,058

Related_Party_Transactions_Rel1

Related Party Transactions - Related Party Transactions (Parenthetical) (Detail)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2014
Bayonne Energy Center LLC [Member]
Related Party Transaction [Line Items]
Joint venture ownership interest percentage	50.00%	50.00%	50.00%
WilcoHess [Member]
Related Party Transaction [Line Items]
Joint venture ownership interest percentage				56.00%

Related_Party_Transactions_Cor

Related Party Transactions - Corporation's Related Party Accounts Receivable (Payable) (Detail) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
WilcoHess [Member]
Related Party Transaction [Line Items]
Accounts receivable (payable) with related parties	$114
Bayonne Energy Center LLC [Member]
Related Party Transaction [Line Items]
Accounts receivable (payable) with related parties	($4)

Financial_Risk_Management_and_2

Financial Risk Management and Trading Activities - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Voting interest in trading partnership	50.00%

Financial_Risk_Management_and_3

Financial Risk Management and Trading Activities - Gross Volumes of Corporation's Derivative Contracts Outstanding (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Interest rate swap [Member]
Derivative [Line Items]
Derivative notional amount	$1,300	$865
Gross Volumes of the Financial Risk Management Derivative Contracts Outstanding [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Derivative notional amount	1,189	220
Gross Volumes of the Financial Risk Management Derivative Contracts Outstanding [Member] | Interest rate swap [Member]
Derivative [Line Items]
Derivative notional amount	1,300	865
Gross Volumes of the Financial Risk Management Derivative Contracts Outstanding [Member] | Commodity, Primarily Crude Oil (Millions of Barrels) [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts		9
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Foreign Exchange [Member]
Derivative [Line Items]
Derivative notional amount	77	52
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Interest rate swap [Member]
Derivative [Line Items]
Derivative notional amount	$29
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Crude Oil and Refined Petroleum Products [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts	1,396	1,815
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Natural Gas (Millions of mcf) [Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts	2,224	2,735
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Electricity (Millions of megawatt hours)[Member]
Derivative [Line Items]
Absolute volume of derivative commodity contracts	1	1
Gross Volumes of Derivative Contracts Outstanding Relating to Trading Activities [Member] | Equity Securities (Millions of Shares) [Member]
Derivative [Line Items]
Equity securities	5	11

Financial_Risk_Management_and_4

Financial Risk Management and Trading Activities - Corporate Financial Risk Management Activities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Interest rate swap [Member]
Derivative [Line Items]
Derivative notional amount	$1,300	$865
Sales and other operating revenues [Member]
Derivative [Line Items]
Realized gains (losses) from E&P hedging activities due to the increase (decrease) in sales and other operating revenue	193	39	-688
Realized gains (losses) from E&P hedging activities net of income taxes	121	25	-431
Interest Rate Swaps and Fixed-rate Debt [Member]
Derivative [Line Items]
Change in the fair value of interest rate swaps - increase/(decrease)	1	-35
Corporate Risk Management [Member] | New Brent Crude Hedges [Member]
Derivative [Line Items]
After-tax deferred gains in Accumulated other comprehensive income (loss)	0
Corporate Risk Management [Member] | West Texas Intermediate
Derivative [Line Items]
After-tax deferred gains in Accumulated other comprehensive income (loss)	0
Corporate Risk Management [Member] | Brent and West Texas Intermediate Crude Hedges [Member]
Derivative [Line Items]
Gain (loss) on ineffectiveness reflected in earnings	$0	$0	($9)

Financial_Risk_Management_and_5

Financial Risk Management and Trading Activities - Net Realized and Unrealized Pre-Tax Gains (Losses) on Derivative Contracts Used in Corporate Risk Management Activities and Not Designated as Hedges (Detail) (Not Designated as Hedging Instrument [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments Gain Loss [Line Items]
Net realized and unrealized pre-tax gains (losses) on derivative contracts used in Corporate Risk Management activities and not designated as hedges	$117	($39)	$44
Commodity [Member]
Derivative Instruments Gain Loss [Line Items]
Net realized and unrealized pre-tax gains (losses) on derivative contracts used in Corporate Risk Management activities and not designated as hedges			1
Foreign Exchange [Member]
Derivative Instruments Gain Loss [Line Items]
Net realized and unrealized pre-tax gains (losses) on derivative contracts used in Corporate Risk Management activities and not designated as hedges	$117	($39)	$43

Financial_Risk_Management_and_6

Financial Risk Management and Trading Activities - Trading Activities - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Percentage of information disclosed for trading partnership	100.00%

Financial_Risk_Management_and_7

Financial Risk Management and Trading Activities - Pre-Tax Unrealized and Realized Gains (Losses) from Trading Activities (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments Gain Loss [Line Items]
Pre-tax unrealized and realized gains (losses) from trading activities	$202	$79	$117
Commodity [Member]
Derivative Instruments Gain Loss [Line Items]
Pre-tax unrealized and realized gains (losses) from trading activities	168	78	104
Foreign Exchange [Member]
Derivative Instruments Gain Loss [Line Items]
Pre-tax unrealized and realized gains (losses) from trading activities	2		3
Other [Member]
Derivative Instruments Gain Loss [Line Items]
Pre-tax unrealized and realized gains (losses) from trading activities	$32	$1	$10

Financial_Risk_Management_and_8

Financial Risk Management and Trading Activities - Netting Arrangements on Physical and Financial Derivative Assets and (Liabilities) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives Fair Value [Line Items]
Gross Amounts, Assets	$7,541	$3,137
Physical Derivative and Financial Instruments, Assets	-6,734	-2,083
Cash Collateral, Assets	-37	-79
Net Amounts Presented in the Consolidated Balance Sheet, Assets	770	975
Gross Amounts Not Offset in the Consolidated Balance Sheet, Assets	-4	-44
Net Amounts, Assets	766	931
Gross Amounts, Liabilities	-7,884	-3,224
Physical Derivative and Financial Instruments, Liabilities	6,734	2,083
Cash Collateral, Liabilities	302	168
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-848	-973
Gross Amounts Not Offset in the Consolidated Balance Sheet, Liabilities	4	44
Net Amounts, Liabilities	-844	-929
Commodity [Member]
Derivatives Fair Value [Line Items]
Gross Amounts, Assets	7,465	3,086
Physical Derivative and Financial Instruments, Assets	-6,664	-1,867
Cash Collateral, Assets	-36	-79
Net Amounts Presented in the Consolidated Balance Sheet, Assets	765	1,140
Gross Amounts Not Offset in the Consolidated Balance Sheet, Assets	-3	-41
Net Amounts, Assets	762	1,099
Gross Amounts, Liabilities	-7,871	-3,212
Physical Derivative and Financial Instruments, Liabilities	6,664	1,867
Cash Collateral, Liabilities	299	168
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-908	-1,177
Gross Amounts Not Offset in the Consolidated Balance Sheet, Liabilities	3	41
Net Amounts, Liabilities	-905	-1,136
Interest Rate And Other
Derivatives Fair Value [Line Items]
Gross Amounts, Assets	76	51
Physical Derivative and Financial Instruments, Assets	-7	-10
Cash Collateral, Assets	-1
Net Amounts Presented in the Consolidated Balance Sheet, Assets	68	41
Gross Amounts Not Offset in the Consolidated Balance Sheet, Assets	-1	-3
Net Amounts, Assets	67	38
Gross Amounts, Liabilities	-13
Physical Derivative and Financial Instruments, Liabilities	7
Cash Collateral, Liabilities	3
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Liabilities	1
Net Amounts, Liabilities	-2
Counterparty Netting
Derivatives Fair Value [Line Items]
Physical Derivative and Financial Instruments, Assets	-63	-206
Net Amounts Presented in the Consolidated Balance Sheet, Assets	-63	-206
Net Amounts, Assets	-63	-206
Physical Derivative and Financial Instruments, Liabilities	63	206
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	63	206
Net Amounts, Liabilities	63	206
Other [Member]
Derivatives Fair Value [Line Items]
Gross Amounts, Liabilities		-12
Physical Derivative and Financial Instruments, Liabilities		10
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities		-2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Liabilities		3
Net Amounts, Liabilities		$1

Financial_Risk_Management_and_9

Financial Risk Management and Trading Activities - Fair Value Measurements - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative [Line Items]
Net Amounts, Assets	$766	$931
Net Amounts, Liabilities	-844	-929
Discontinued Operations [Member]
Derivative [Line Items]
Net Amounts, Assets	701	612
Net Amounts, Liabilities	($845)	($620)

Recovered_Sheet1

Financial Risk Management and Trading Activities - Gross and Net Fair Values of Corporate and Energy Marketing Risk Management and Trading Derivative Instruments (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives Fair Value [Line Items]
Cash collateral (received) posted	$17	$31
Accounts Receivable
Derivatives Fair Value [Line Items]
Gross fair value of derivative contracts	7,541	3,137
Master netting arrangements	-6,734	-2,083
Cash collateral (received) posted	-37	-79
Net fair value of derivative contracts	770	975
Derivative contracts designated as hedging instruments	39	47
Derivative contracts not designated as hedging instruments	7,502	3,090
Accounts Receivable | Commodity [Member]
Derivatives Fair Value [Line Items]
Derivative contracts designated as hedging instruments		11
Derivative contracts not designated as hedging instruments	7,465	3,075
Accounts Receivable | Interest Rate And Other
Derivatives Fair Value [Line Items]
Derivative contracts designated as hedging instruments	39	36
Accounts Receivable | Foreign Exchange [Member]
Derivatives Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	31	2
Accounts Receivable | Other [Member]
Derivatives Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	6	13
Accounts Payable
Derivatives Fair Value [Line Items]
Derivative contracts designated as hedging instruments	-2	-4
Derivative contracts not designated as hedging instruments	-7,882	-3,220
Gross fair value of derivative contracts	-7,884	-3,224
Master netting arrangements	6,734	2,083
Cash collateral (received) posted	302	168
Net fair value of derivative contracts	-848	-973
Accounts Payable | Commodity [Member]
Derivatives Fair Value [Line Items]
Derivative contracts designated as hedging instruments		-3
Derivative contracts not designated as hedging instruments	-7,871	-3,209
Accounts Payable | Interest Rate And Other
Derivatives Fair Value [Line Items]
Derivative contracts designated as hedging instruments	-2	-1
Accounts Payable | Foreign Exchange [Member]
Derivatives Fair Value [Line Items]
Derivative contracts not designated as hedging instruments		-3
Accounts Payable | Other [Member]
Derivatives Fair Value [Line Items]
Derivative contracts not designated as hedging instruments	($11)	($8)

Recovered_Sheet2

Financial Risk Management and Trading Activities - Fair Values for Corporation's Net Physical Derivative and Financial Assets and (Liabilities) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Collateral and counterparty netting (Assets)	($63)	($206)
Net Amounts Presented in the Consolidated Balance Sheet, Assets	770	975
Other assets measured at fair value on a recurring basis	27
Total assets measured at fair value on a recurring basis	797	975
Collateral and counterparty netting (Liabilities)	63	206
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-848	-973
Other liabilities measured at fair value on a recurring basis	-40	-31
Total liabilities measured at fair value on a recurring basis	-888	-1,004
Other fair value measurement disclosures Long-term debt	-7,003	-6,641
Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	765	1,140
Net Amounts Presented in the Consolidated Balance Sheet, Assets	765	1,140
Total derivative contracts (Liabilities)	-908	-1,177
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-908	-1,177
Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	68	41
Net Amounts Presented in the Consolidated Balance Sheet, Assets	68	41
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-3
Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)	-3	-2
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities		-2
Level 1 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Collateral and counterparty netting (Assets)	-43	-15
Net Amounts Presented in the Consolidated Balance Sheet, Assets	711	241
Other assets measured at fair value on a recurring basis	27
Total assets measured at fair value on a recurring basis	738	241
Collateral and counterparty netting (Liabilities)	43	15
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-298	-82
Other liabilities measured at fair value on a recurring basis	-40	-31
Total liabilities measured at fair value on a recurring basis	-338	-113
Level 1 [Member] | Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	755	254
Total derivative contracts (Liabilities)	-338	-97
Level 1 [Member] | Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	-1	2
Level 1 [Member] | Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)	-3
Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Collateral and counterparty netting (Assets)	-20	-191
Net Amounts Presented in the Consolidated Balance Sheet, Assets	440	425
Total assets measured at fair value on a recurring basis	440	425
Collateral and counterparty netting (Liabilities)	20	191
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-1,246	-883
Total liabilities measured at fair value on a recurring basis	-1,246	-883
Other fair value measurement disclosures Long-term debt	-7,003	-6,641
Level 2 [Member] | Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	390	579
Total derivative contracts (Liabilities)	-1,265	-1,071
Level 2 [Member] | Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	70	37
Level 2 [Member] | Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)	-1	-3
Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Net Amounts Presented in the Consolidated Balance Sheet, Assets	114	497
Total assets measured at fair value on a recurring basis	114	497
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	-64	-285
Total liabilities measured at fair value on a recurring basis	-64	-285
Level 3 [Member] | Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	114	494
Total derivative contracts (Liabilities)	-62	-285
Level 3 [Member] | Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)		3
Level 3 [Member] | Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)	-2
Counterparty Netting
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Net Amounts Presented in the Consolidated Balance Sheet, Assets	-458	-109
Total assets measured at fair value on a recurring basis	-458	-109
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	458	109
Total liabilities measured at fair value on a recurring basis	458	109
Counterparty Netting | Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	-458	-108
Total derivative contracts (Liabilities)	458	108
Counterparty Netting | Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)		-1
Counterparty Netting | Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)		1
Collateral [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Net Amounts Presented in the Consolidated Balance Sheet, Assets	-37	-79
Total assets measured at fair value on a recurring basis	-37	-79
Net Amounts Presented in the Consolidated Balance Sheet, Liabilities	302	168
Total liabilities measured at fair value on a recurring basis	302	168
Collateral [Member] | Commodity [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	-36	-79
Total derivative contracts (Liabilities)	299	168
Collateral [Member] | Interest Rate And Other
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Assets)	-1
Collateral [Member] | Other [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total derivative contracts (Liabilities)	$3

Recovered_Sheet3

Financial Risk Management and Trading Activities - Fair Values for Corporation's Net Physical Derivative and Financial Assets and (Liabilities) (Parenthetical) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Long-term debt, including current maturities	$5,987	$5,798

Recovered_Sheet4

Financial Risk Management and Trading Activities - Net Transfers into and Out of Each Level of Fair Value Hierarchy (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Level 1 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value measurements net transfers in	$25	$3
Fair value measurements net transfers out	-47	76
Fair Value Measurements Net Transfers Into Or Out Of, Total	-22	79
Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value measurements net transfers in	25	-113
Fair value measurements net transfers out	-128	88
Fair Value Measurements Net Transfers Into Or Out Of, Total	-103	-25
Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value measurements net transfers in	105	-85
Fair value measurements net transfers out	20	31
Fair Value Measurements Net Transfers Into Or Out Of, Total	$125	($54)

Recovered_Sheet5

Financial Risk Management and Trading Activities - Changes in Physical Derivatives and Financial Assets and (Liabilities) Primarily Related to Commodities that are Measured at Fair Value Based on Level 3 Inputs (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Balance at beginning of period	$212	$141
Unrealized pre-tax gains (losses) included in earnings	-298	175
Purchases	31	45
Sales	-24	-34
Settlements	4	-61
Transfers into Level 3	105	-85
Transfers out of Level 3	20	31
Balance at end of period	$50	$212

Recovered_Sheet6

Financial Risk Management and Trading Activities - Commodity Contracts with a Fair Value (Detail)	Dec. 31, 2014	Dec. 31, 2013
Minimum [Member] | Contract Prices | Crude Oil and Refined Petroleum Products [Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	36.27	78.45
Range of measurement of liabilities for recurring inputs	36.27	57.45
Minimum [Member] | Contract Prices | Electricity (Millions of megawatt hours)[Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	38.8	19.52
Range of measurement of liabilities for recurring inputs		26.48
Minimum [Member] | Basis Prices [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	-0.61	-4.99
Range of measurement of liabilities for recurring inputs	2.84	-1.9
Minimum [Member] | Contract volatilities [Member] | Crude Oil and Refined Petroleum Products [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	32.00%	16.00%
Percentage range of measurement of liabilities for recurring inputs	32.00%	16.00%
Minimum [Member] | Contract volatilities [Member] | Electricity (Millions of megawatt hours)[Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs		16.00%
Percentage range of measurement of liabilities for recurring inputs		16.00%
Minimum [Member] | Contract volatilities [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	19.00%	17.00%
Percentage range of measurement of liabilities for recurring inputs	23.00%	34.00%
Maximum [Member] | Contract Prices | Crude Oil and Refined Petroleum Products [Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	122.66	228.86
Range of measurement of liabilities for recurring inputs	85.4	183.89
Maximum [Member] | Contract Prices | Electricity (Millions of megawatt hours)[Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	71.69	165.75
Range of measurement of liabilities for recurring inputs		155.33
Maximum [Member] | Basis Prices [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	13.5	18.1
Range of measurement of liabilities for recurring inputs	4.45	18
Maximum [Member] | Contract volatilities [Member] | Crude Oil and Refined Petroleum Products [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	45.00%	18.00%
Percentage range of measurement of liabilities for recurring inputs	45.00%	17.00%
Maximum [Member] | Contract volatilities [Member] | Electricity (Millions of megawatt hours)[Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs		36.00%
Percentage range of measurement of liabilities for recurring inputs		36.00%
Maximum [Member] | Contract volatilities [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	53.00%	35.00%
Percentage range of measurement of liabilities for recurring inputs	53.00%	35.00%
Weighted Average [Member] | Contract Prices | Crude Oil and Refined Petroleum Products [Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	65.63	118.68
Range of measurement of liabilities for recurring inputs	69.54	122.54
Weighted Average [Member] | Contract Prices | Electricity (Millions of megawatt hours)[Member] | Commodity [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	57.22	45.76
Range of measurement of liabilities for recurring inputs		43.12
Weighted Average [Member] | Basis Prices [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range of measurement of assets for recurring inputs	6.19	0.23
Range of measurement of liabilities for recurring inputs	2.94	-0.62
Weighted Average [Member] | Contract volatilities [Member] | Crude Oil and Refined Petroleum Products [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	43.00%	17.00%
Percentage range of measurement of liabilities for recurring inputs	41.00%	17.00%
Weighted Average [Member] | Contract volatilities [Member] | Electricity (Millions of megawatt hours)[Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs		23.00%
Percentage range of measurement of liabilities for recurring inputs		22.00%
Weighted Average [Member] | Contract volatilities [Member] | Natural Gas [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Percentage range of measurement of assets for recurring inputs	40.00%	22.00%
Percentage range of measurement of liabilities for recurring inputs	41.00%	35.00%

Recovered_Sheet7

Financial Risk Management and Trading Activities - Commodity Contracts with a Fair Value (Parenthetical) (Detail) (Commodity [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Total derivative contracts (Assets)	$765	$1,140
Total derivatives contract (liabilities)	908	1,177
Level 3 [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Total derivative contracts (Assets)	114	494
Total derivatives contract (liabilities)	$62	$285

Recovered_Sheet8

Financial Risk Management and Trading Activities - Credit Risk - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Cash held from counterparties	$37	$79
Cash posted to counterparties	302	168
Outstanding letters of credit	397	410
Net liability related to both realized and unrealized derivative contracts with contingent collateral provisions	130	281
Cash collateral (received) posted	17	31
Additional collateral	55	134
Discontinued Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Outstanding letters of credit	$240	$302
Integrated Oil Companies [Member] | Continuing Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	23.00%	45.00%
Refiners [Member] | Continuing Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	14.00%	18.00%
Financial Institutions [Member] | Continuing Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	22.00%	14.00%
Government Entities [Member] | Continuing Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	18.00%	8.00%
Trading Companies [Member] | Continuing Operations [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	13.00%	7.00%

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	12 Months Ended	1 Months Ended
In Billions, unless otherwise specified	Dec. 31, 2014	Jan. 31, 2015	Feb. 28, 2015
Subsequent Event [Line Items]
Interest rate on the borrowings on the credit facility description	1.25% above the London Interbank Offered Rate.
Credit facility fee (per annum)	0.25%
Maturity of revolving credit facilities	2016-04
New syndicated revolving credit facility maturing in April 2016	$4
Subsequent Event
Subsequent Event [Line Items]
New syndicated revolving credit facility		$4
Interest rate on the borrowings on the credit facility description		1.075% above the London Interbank Offered Rate
Credit facility fee (per annum)		0.18%
Maturity of revolving credit facilities		2020-01
Subsequent Event | HETCO [Member]
Subsequent Event [Line Items]
Interest sold in energy trading joint venture, HETCO			In February 2015, the Corporation sold its interest in the energy trading joint venture, HETCO, which was renamed Hartree Partners, LP. Pursuant to the terms of the sale, Hartree is permitted to continue to utilize the Corporation’s guarantees issued in favor of Hartree's existing counterparties until November 12, 2015, provided that new trades are for a period of one year or less, comply with certain credit requirements, and net exposures remain within VAR limits previously applied by the Corporation.
Maximum guarantee period on trading joint venture, HETCO			12-Nov-15

Schedule_VALUATION_AND_QUALIFY

Schedule - VALUATION AND QUALIFYING ACCOUNTS (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Losses on receivables [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning Balance	$27	$34	$55
Charged to Costs and Expenses		10
Deductions from Reserves	14	17	21
Ending Balance	13	27	34
Deferred income tax valuation [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning Balance	1,519	1,282	1,071
Charged to Costs and Expenses	142	383	248
Charged to Other Accounts	-1	-17
Deductions from Reserves	244	129	37
Ending Balance	$1,416	$1,519	$1,282