Hess (HES) 10-K 23 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Jun. 30, 2016
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Trading Symbol	HES
Entity Registrant Name	HESS CORP
Entity Central Index Key	4,447
Current Fiscal Year End Date	--12-31
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	316,523,200
Entity Public Float		$ 16,770,000,000

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents		$ 2,732	$ 2,716
Accounts receivable
Trade		940	847
Other		86	312
Inventories		323	399
Other current assets		195	130
Total current assets		4,276	4,404
Property, plant and equipment:
Total — at cost		46,907	46,826
Less: Reserves for depreciation, depletion, amortization and lease impairment		23,312	20,474
Property, plant and equipment — net	[1]	23,595	26,352
Goodwill		375	375
Deferred income taxes		59	2,653
Other assets		316	373
Total Assets		28,621	34,157
Current Liabilities:
Accounts payable		433	457
Accrued liabilities		1,609	1,997
Taxes payable		97	88
Current maturities of long-term debt		112	86
Total current liabilities		2,251	2,628
Long-term debt		6,694	6,506
Deferred income taxes		1,144	1,334
Asset retirement obligations		1,912	2,158
Other liabilities and deferred credits		1,029	1,130
Total Liabilities		13,030	13,756
Hess Corporation stockholders’ equity:
Preferred stock Series A 8% cumulative mandatory convertible , par value $1.00. Authorized —20,000,000 shares; $1,000 per share liquidation preference; Issued — 575,000 shares (2015: nil)		1	0
Common stock, par value $1.00; Authorized — 600,000,000 shares Issued — 316,523,200 shares (2015: 286,045,586)		317	286
Capital in excess of par value		5,773	4,127
Retained earnings		10,147	16,637
Accumulated other comprehensive income (loss)		(1,704)	(1,664)
Total Hess Corporation stockholders’ equity		14,534	19,386
Noncontrolling interests		1,057	1,015
Total equity		15,591	20,401
Total Liabilities and Equity		$ 28,621	$ 34,157
[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1
Preferred stock, shares authorized	20,000,000
Preferred stock, shares issued	575,000
Preferred stock, liquidation preference per share	$ 1,000
Cumulative mandatory convertible series	8.00%
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	316,523,200	286,045,586

Statement of Consolidated Incom

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues and Non-Operating Income
Sales and other operating revenues	$ 4,762	$ 6,636	$ 10,737
Gains on asset sales, net	23	51	823
Other, net	59	(126)	(121)
Total revenues and non-operating income	4,844	6,561	11,439
Costs and Expenses
Cost of products sold (excluding items shown separately below)	1,063	1,294	1,719
Operating costs and expenses	1,880	2,029	2,034
Production and severance taxes	101	146	275
Exploration expenses, including dry holes and lease impairment	1,442	881	840
General and administrative expenses	415	557	588
Interest expense	338	341	323
Loss on debt extinguishment	148	0	0
Depreciation, depletion and amortization	3,244	3,955	3,224
Impairment	67	1,616	0
Total costs and expenses	8,698	10,819	9,003
Income (Loss) from Continuing Operations Before Income Taxes	(3,854)	(4,258)	2,436
Provision (benefit) for income taxes	2,222	(1,299)	744
Income (Loss) from Continuing Operations	(6,076)	(2,959)	1,692
Income (Loss) from Discontinued Operations, Net of Income Taxes	0	(48)	682
Net Income (Loss)	(6,076)	(3,007)	2,374
Less: Net income (loss) attributable to noncontrolling interests	56	49	57
Net Income (Loss) Attributable to Hess Corporation	(6,132)	(3,056)	2,317
Less: Preferred stock dividends	41	0	0
Net Income (Loss) Applicable to Hess Corporation Common Stockholders	$ (6,173)	$ (3,056)	$ 2,317
Net Income (Loss) Per Common Share - Basic:
Continuing operations	$ (19.92)	$ (10.61)	$ 5.57
Discontinued operations	0	(0.17)	2.06
Net Income (Loss) Per Common Share	(19.92)	(10.78)	7.63
Net Income (Loss) Per Common Share - Diluted:
Continuing operations	(19.92)	(10.61)	5.50
Discontinued operations	0	(0.17)	2.03
Net Income (Loss) Per Common Share	$ (19.92)	$ (10.78)	$ 7.53
Weighted Average Number of Common Shares Outstanding (Diluted)	309.9	283.6	307.7
Common Stock Dividends Per Share	$ 1	$ 1	$ 1

Statement of Consolidated Compr

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ (6,076)	$ (3,007)	$ 2,374
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	0	(118)	(137)
Income taxes on effect of hedge (gains) losses reclassified to income	0	44	51
Net effect of hedge (gains) losses reclassified to income	0	(74)	(86)
Change in fair value of cash flow hedges	0	121	128
Income taxes on change in fair value of cash flow hedges	0	(45)	(48)
Net change in fair value of cash flow hedges	0	76	80
Change in derivatives designated as cash flow hedges, after taxes	0	2	(6)
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	(155)	17	(534)
Income taxes on actuarial changes in plan liabilities	20	4	186
(Increase) reduction in unrecognized actuarial losses, net	(135)	21	(348)
Amortization of net actuarial losses	60	92	56
Income taxes on amortization of net actuarial losses	(21)	(31)	(18)
Net effect of amortization of net actuarial losses	39	61	38
Recognition of accumulated actuarial losses - HOVENSA	0	15	0
Income taxes on recognition of accumulated actuarial losses - HOVENSA	0	(9)	0
Recognition of accumulated actuarial losses, net of taxes - HOVENSA	0	6	0
Change in pension and other postretirement plans, after taxes	(96)	88	(310)
Foreign currency translation adjustment
Foreign currency translation adjustment	56	(344)	(756)
Change in foreign currency translation adjustment	56	(344)	(756)
Other Comprehensive Income (Loss)	(40)	(254)	(1,072)
Comprehensive Income (Loss)	(6,116)	(3,261)	1,302
Less: Comprehensive income (loss) attributable to noncontrolling interests	56	49	57
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (6,172)	$ (3,310)	$ 1,245

Statement of Consolidated Cash

Statement of Consolidated Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows From Operating Activities
Net income (loss)	$ (6,076)	$ (3,007)	$ 2,374
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
(Gains) losses on asset sales, net	(23)	(51)	(823)
Depreciation, depletion and amortization	3,244	3,955	3,224
Impairment	67	1,616	0
Loss from equity affiliates	0	25	84
Exploratory dry hole costs	1,064	410	301
Exploration lease and other impairment	145	182	207
Stock compensation expense	73	97	87
Provision (benefit) for deferred income taxes and other tax accruals	2,200	(1,319)	270
Loss on debt extinguishment	148	0	0
(Income) loss from discontinued operations, net of income taxes	0	48	(682)
Changes in operating assets and liabilities
(Increase) decrease in accounts receivable	96	841	(199)
(Increase) decrease in inventories	77	29	62
Increase (decrease) in accounts payable and accrued liabilities	(87)	(424)	79
Increase (decrease) in taxes payable	9	(222)	(108)
Changes in other operating assets and liabilities	(142)	(164)	(372)
Cash provided by (used in) operating activities - continuing operations	795	2,016	4,504
Cash provided by (used in) operating activities - discontinued operations	0	(35)	(47)
Net cash provided by (used in) operating activities	795	1,981	4,457
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(1,979)	(3,956)	(4,867)
Additions to property, plant and equipment - Bakken Midstream	(272)	(365)	(347)
Proceeds from asset sales	140	50	2,978
Other, net	21	(44)	(192)
Cash provided by (used in) investing activities - continuing operations	(2,090)	(4,315)	(2,428)
Cash provided by (used in) investing activities - discontinued operations	0	109	2,436
Net cash provided by (used in) investing activities	(2,090)	(4,206)	8
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	43	110	0
Debt with maturities of greater than 90 days – Borrowings	1,496	600	598
Debt with maturities of greater than 90 days – Repayments	(1,455)	(67)	(590)
Proceeds from issuance of preferred stock	557	0	0
Proceeds from issuance of common stock	1,087	0	0
Common stock acquired and retired	0	(142)	(3,715)
Cash dividends paid	(350)	(287)	(303)
Employee stock options exercised, including income tax benefits	12	12	182
Noncontrolling interests, net	(23)	2,296	0
Other, net	(56)	(25)	0
Cash provided by (used in) financing activities - continuing operations	1,311	2,497	(3,828)
Cash provided by (used in) financing activities - discontinued operations	0	0	(7)
Net cash provided by (used in) financing activities	1,311	2,497	(3,835)
Net Increase (Decrease) in Cash and Cash Equivalents	16	272	630
Cash and Cash Equivalents at Beginning of Year	2,716	2,444	1,814
Cash and Cash Equivalents at End of Year	$ 2,732	$ 2,716	$ 2,444

Statement of Consolidated Equit

Statement of Consolidated Equity - USD ($) $ in Millions	Total	Mandatory Convertible Preferred Stock	Common Stock	Capital in Excess of Par	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Total Hess Stockholders' Equity	Noncontrolling Interests
Balance at Dec. 31, 2013	$ 24,784	$ 0	$ 325	$ 3,498	$ 21,235	$ (338)	$ 24,720	$ 64
Net income (loss)	2,374	0	0	0	2,317	0	2,317	57
Other comprehensive income (loss)	(1,072)	0	0	0	0	(1,072)	(1,072)	0
Share-based compensation, including income taxes	265	0	4	261	0	0	265	0
Dividends on common stock	(303)	0	0	0	(303)	0	(303)	0
Common stock acquired and retired	(3,722)	0	(43)	(482)	(3,197)	0	(3,722)	0
Noncontrolling interests, net	(6)	0	0	0	0	0	0	(6)
Balance at Dec. 31, 2014	22,320	0	286	3,277	20,052	(1,410)	22,205	115
Net income (loss)	(3,007)	0	0	0	(3,056)	0	(3,056)	49
Other comprehensive income (loss)	(254)	0	0	0	0	(254)	(254)	0
Share-based compensation, including income taxes	106	0	1	105	0	0	106	0
Dividends on common stock	(287)	0	0	0	(287)	0	(287)	0
Common stock acquired and retired	(91)	0	(1)	(18)	(72)	0	(91)	0
Formation of Bakken Midstream joint venture	2,061	0	0	763	0	0	763	1,298
Noncontrolling interests, net	(447)	0	0	0	0	0	0	(447)
Balance at Dec. 31, 2015	20,401	0	286	4,127	16,637	(1,664)	19,386	1,015
Net income (loss)	(6,076)	0	0	0	(6,132)	0	(6,132)	56
Other comprehensive income (loss)	(40)	0	0	0	0	(40)	(40)	0
Stock issuance	1,607	1	29	1,577	0	0	1,607	0
Share-based compensation, including income taxes	71	0	2	69	0	0	71	0
Dividends on preferred stock	(41)	0	0	0	(41)	0	(41)	0
Dividends on common stock	(317)	0	0	0	(317)	0	(317)	0
Common stock acquired and retired	0
Noncontrolling interests, net	(14)	0	0	0	0	0	0	(14)
Balance at Dec. 31, 2016	$ 15,591	$ 1	$ 317	$ 5,773	$ 10,147	$ (1,704)	$ 14,534	$ 1,057

Nature of Operations, Basis of

Nature of Operations, Basis of Presentation and Summary of Accounting Policies	12 Months Ended
	Dec. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Nature of Operations, Basis of Presentation and Summary of Accounting Policies	HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 1. Nature of Operations, Basis of Presentation and Summary of Accounting Policies Unless the context indicates otherwise, references to “Hess”, “the Corporation”, “Registrant”, “we”, “us” and “our” refer to the consolidated business operations of Hess Corporation and its affiliates. Nature of Business: Hess Corporation is a global Exploration and Production (E&P) company engaged in exploration, development, production, transportation, purchase and sale of crude oil, natural gas liquids, and natural gas with production operations located primarily in the United States (U.S.), Denmark, Equatorial Guinea, the Malaysia/Thailand Joint Development Area (JDA), Malaysia, and Norway. The Bakken Midstream operating segment, which was established in the second quarter of 2015, provides fee-based services, including gathering, compressing and processing natural gas and fractionating natural gas liquids, or NGLs; gathering, terminaling, loading and transporting crude oil and NGLs; and storing and terminaling propane, primarily in the Bakken and Three Forks Shale plays in the Williston Basin area of North Dakota. Basis of Presentation and Principles of Consolidation: The consolidated financial statements include the accounts of Hess Corporation and entities in which we own more than a 50% voting interest. We also consolidate Hess Infrastructure Partners LP (HIP), a variable interest entity, based on our conclusion that we have the power through our 50% ownership to direct those activities that most significantly impact the economic performance of HIP, and are obligated to absorb losses or have the right to receive benefits that could potentially be significant to HIP. Our undivided interests in unincorporated oil and gas exploration and production ventures are proportionately consolidated. Investments in affiliated companies, 20% to 50% owned and where we have the ability to influence the operating or financial decisions of the affiliate, are accounted for using the equity method. In 2016, we adopted Accounting Standard Update (ASU) 2015-03, Simplifying the Presentation of Debt Issuance Costs Consolidated Balance Sheet In 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements – Going Concern 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 E&P segment recognizes revenue from the sale of crude oil, natural gas liquids, and natural gas, when title passes to the customer. Differences between E&P natural gas volumes sold and our entitlement share of natural gas production are not material. In our E&P activities, we engage 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 Our Bakken Midstream segment recognizes revenue from fee-based services including crude oil and natural gas gathering, processing of natural gas and the fractionation of natural gas liquids, terminaling and loading crude oil and natural gas liquids, transportation of crude oil by rail car and the storage and terminaling of propane when pervasive evidence of an arrangement exists, delivery has occurred or services rendered, price is fixed or determinable, and collectability is reasonably assured. 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 CO 2 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: We record 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 facilities 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: We review 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 prevailing low crude oil price environment, we tested our oil and gas properties for impairment. See Note 6, Impairment . Impairment of Goodwill: Goodwill is tested for impairment annually on October 1 st Note 6, Impairment. 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. Income Taxes: Deferred income taxes are determined using the liability method. We have net operating loss carryforwards or credit carryforwards in multiple jurisdictions and have recorded deferred tax assets for those losses and credits. Additionally, we have 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, when tested under the relevant accounting standards, 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. The accounting standards require the evaluation of all available positive and negative evidence giving weight based on the evidence’s relative objectivity. In evaluating potential sources of positive evidence, we consider the reversal of taxable temporary differences, taxable income in carryback and carryforward periods, the availability of tax planning strategies, the existence of appreciated assets, estimates of future taxable income, and other factors. In evaluating potential sources of negative evidence, we consider a cumulative loss in recent years, any history of operating losses or tax credit carryforwards expiring unused, losses expected in early future years, unsettled circumstances that, if unfavorably resolved, would adversely affect future operations and profit levels on a continuing basis in future years, and carryback or carryforward periods that are so brief that it would limit realization of tax benefits if a significant deductible temporary difference is expected to reverse in a single year. We assign cumulative historical losses significant weight in the evaluation of realizability relative to more subjective evidence such as forecasts of future income. In addition, we recognize 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. We do not provide for deferred U.S. income taxes for that portion of undistributed earnings of foreign subsidiaries that are indefinitely reinvested in foreign operations. We classify interest and penalties associated with uncertain tax positions as income tax expense. Asset Retirement Obligations: We have material legal obligations to remove and dismantle long‑lived assets and to restore land or the seabed at certain exploration and production locations. We initially recognize a liability for the fair value of legally required asset retirement obligations in the period in which the retirement obligations are incurred, and capitalize the associated asset retirement costs as part of the carrying amount of the long‑lived assets. In subsequent periods, the liability is accreted, and the asset is depreciated over the useful life of the related asset. Fair value is determined by applying a credit adjusted risk-free rate to the undiscounted expected future abandonment expenditures, which represent Level 3 inputs in the fair value hierarchy defined under Fair Value Measurements below. Retirement Plans: We recognize 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. We recognize the net changes in the funded status of these plans in the year in which such changes occur. 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 or the remaining average expected life if a plan’s participants are predominantly inactive. Derivatives: We utilize derivative instruments for financial risk management activities. In these activities, we may use futures, forwards, options and swaps, individually or in combination, to mitigate our exposure to fluctuations in prices of crude oil and natural gas, as well as changes in interest and foreign currency exchange rates. All derivative instruments are recorded at fair value in our Consolidated Balance Sheet Fair Value Measurements: We use various valuation approaches in determining fair value for financial instruments, including the market and income approaches. Our fair value measurements also include non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and our credit is considered for accrued liabilities. We also record 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. We determine 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), including discounted cash flows and other unobservable data. 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. 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. Netting of Financial Instruments: We generally enter 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 our intent and practice is to offset amounts in the case of such a termination, our policy is to record the fair value of derivative assets and liabilities on a net basis. In the normal course of business, we rely 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 us, “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. We are 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. Share-based Compensation: We account for share-based compensation under the fair value method of accounting. 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. We estimate 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 remeasuring 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: We accrue and expense 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 2016, our reserve for estimated remediation liabilities was approximately $80 million. 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 May 2014, the Financial Accounting Standards Board (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 us beginning in the first quarter of 2018, with early adoption permitted from the first quarter of 2017. We have developed a project plan for the implementation of ASC 606 in the first quarter of 2018, and conducted an evaluation of a sample of revenue contracts with customers against the requirements of the standard. Further analysis is planned in 2017 to complete the implementation plan. Based on our assessment to date, we have not identified any changes to the timing of revenue recognition based on the requirements of ASC 606 that would have a material impact on our consolidated financial statements. We plan to adopt ASC 606 using the modified retrospective method that requires application of the new standard prospectively from the date of adoption with a cumulative effect adjustment recorded to retained earnings as of January 1, 2018. In February 2016, the FASB issued ASU 2016-02, Leases In March 2016, the FASB issued Accounting Standards Update (ASU) 2016-09, Improvements to Employee Share-Based Payment Accounting. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses In October 2016, the FASB issued ASU 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory In January 2017, the FASB issued ASU 2017-01, Business Combinations – Clarifying the Definition of a Business In January 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment 1

Common and Preferred Stock Issu

Common and Preferred Stock Issuance	12 Months Ended
	Dec. 31, 2016
Stockholders Equity Note [Abstract]
Common and Preferred Stock Issuance	2. Common and Preferred Stock Issuance In February 2016, we issued 28,750,000 shares of common stock and depositary shares representing 575,000 shares of 8% Series A Mandatory Convertible Preferred Stock (Convertible Preferred Stock), par value $1 per share, with a liquidation preference of $1,000 per share, for total net proceeds of approximately $1.6 billion after deducting underwriting discounts, commissions, and offering expenses. The dividends on the Convertible Preferred Stock will be payable on a cumulative basis. Unless converted earlier, each share of Convertible Preferred Stock will automatically convert into between 21.822 shares and 25.642 shares of our common stock based on the average share price over a period of twenty consecutive trading days ending prior to February 1, 2019 (the “Final Average Price”), subject to anti-dilution adjustments. See Note 17, Outstanding and Weighted Average Common Shares. We also entered into capped call transactions that are expected generally to reduce the potential dilution to our common stock upon conversion of the Convertible Preferred Stock if the Final Average Price exceeds $45.83 per share, subject to anti-dilution adjustments. The number of common shares to be delivered by the counterparties to us will be the value of the capped call transactions at conversion divided by the Final Average Price. The value of the capped call transactions will be zero if the Final Average Price is $45.83 or less and can be up to the capped value of approximately $98 million if the Final Average Price is $53.625 or higher. For any Final Average Price between $45.83 and $53.625, the value of the capped call transactions will be 12.55 million covered shares multiplied by the difference between the Final Average Price and $45.83. The premium paid for the capped call transactions was $37 million, which was recorded against Capital in excess of par in the Statement of Consolidated Equity

Inventories

Inventories	12 Months Ended
	Dec. 31, 2016
Inventory Disclosure [Abstract]
Inventories	3. Inventories Inventories at December 31 were as follows: 2016 2015 (In millions) Crude oil and natural gas liquids $ 77 $ 144 Materials and supplies 246 255 Total Inventories $ 323 $ 399

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2016
Property Plant And Equipment [Abstract]
Property, Plant and Equipment	4. Property, Plant and Equipment Property, plant and equipment at December 31 were as follows: 2016 2015 (In millions) Exploration and Production Unproved properties $ 710 $ 958 Proved properties 4,258 4,202 Wells, equipment and related facilities 38,821 38,738 43,789 43,898 Bakken Midstream 3,018 2,757 Corporate and Other 100 171 Total — at cost 46,907 46,826 Less: Reserves for depreciation, depletion, amortization and lease impairment 23,312 20,474 Property, Plant and Equipment — Net $ 23,595 $ 26,352 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: 2016 2015 2014 (In millions) Balance at January 1 $ 1,415 $ 1,416 $ 2,045 Additions to capitalized exploratory well costs pending the determination of proved reserves 79 424 292 Reclassifications to wells, facilities and equipment based on the determination of proved reserves — (72 ) (629 ) Capitalized exploratory well costs charged to expense (897 ) (356 ) (235 ) Dispositions and other — 3 (57 ) Balance at December 31 $ 597 $ 1,415 $ 1,416 Number of Wells at December 31 17 35 37 Additions to capitalized exploratory well costs primarily related to drilling activity at the Stabroek license offshore Guyana and in the Gulf of Mexico in 2016 and 2015. In 2014, additions related to the Deepwater Tano/Cape Three Points license offshore Ghana and in Kurdistan. Reclassifications to wells, facilities and equipment based on the determination of proved reserves primarily related to Equatorial Guinea in 2015, and the Stampede development project in the Gulf of Mexico in 2014. Capitalized exploratory well costs charged to expense include the following: 2016 : At the Hess-operated Equus natural gas project, offshore the North West Shelf of Australia in the fourth quarter of 2016, we terminated a joint front-end engineering study with a third party natural gas liquefaction joint venture and notified the Australian government of our intent to defer the project. As a result, we expensed all well costs associated with the project, including an exploration well completed in the second quarter of 2016, totaling $830 million. In the second quarter, we expensed costs associated with two exploration wells at the non-operated Sicily project in the Gulf of Mexico where hydrocarbons were encountered but we decided not to pursue the project due to the current price environment and the limited time remaining on the leases. We also expensed the cost of an unsuccessful exploration well at the non-operated Melmar project in the Gulf of Mexico, where noncommercial quantities of hydrocarbons were encountered. 2015 : At the Dinarta Block in the Kurdistan Region of Iraq, we expensed an exploration well resulting from our and our partners’ decision to cease further drilling and relinquish the block. At the Deepwater/Tano Cape Three Points block, offshore Ghana, we expensed well costs primarily related to natural gas discoveries where we were unable to sufficiently progress appraisal negotiations with the regulator, and we expensed three wells with discovered resources offshore Australia that we determined would not be included in the development concept for the Equus project. 2014 : At Green Canyon Block 469 in the Gulf of Mexico, we expensed a previously capitalized exploration well where it was determined no further development activities were planned. The preceding table excludes exploratory dry hole costs of $167 million (2015: $54 million; 2014: $66 million), which were incurred and subsequently expensed in the same year. Exploratory well costs capitalized for greater than one year following completion of drilling were $511 million at December 31, 2016, separated by year of completion as follows (in millions): 2015 $ 238 2014 80 2013 48 2012 145 $ 511 Ghana: Approximately 55% of the capitalized well costs in excess of one year relates to our Deepwater Tano/Cape Three Points license (Hess 50% license interest), offshore Ghana. In 2014 we drilled three successful appraisal wells. Well results continue to be evaluated and development planning is progressing . The government of Côte d’Ivoire has challenged the maritime border between it and the country of Ghana, which includes a portion of our Deepwater Tano/Cape Three Points license. We are unable to proceed with development of this license until there is a resolution of this matter, which may also impact our ability to develop the license. The International Tribunal for Law of the Sea is expected to render a final ruling on the maritime border dispute in 2017. Under terms of our license and subject to resolution of the border dispute, we declared commerciality for four discoveries, including the Pecan Field which would be the primary development hub for the block in March 2016. We are continuing to work with the government on how best to progress work on the block given the maritime border dispute. Guyana: Approximately 20% of the capitalized well costs in excess of one year relates to the Stabroek Block, offshore Guyana (Hess 30% participating interest), where the operator, Esso Exploration and Production Guyana Limited, announced a significant oil discovery at the Liza-1 well in the second quarter of 2015. During 2016, the operator completed a 17,000 square kilometer 3D seismic acquisition on the Stabroek Block and drilled the Liza-2 and Liza-3 wells, both of which encountered hydrocarbons. Pre-development planning is underway and we expect to be in a position to sanction the first phase of the Liza development in 2017. Gulf of Mexico: Approximately 20% of the capitalized well costs in excess of one year relates to an appraisal well in the northern portion of the Shenzi Field (Hess 28% participating interest) in the Gulf of Mexico, where hydrocarbons were encountered in the fourth quarter of 2015. The operator is evaluating plans for developing this area of the field. JDA: Approximately 5% of the capitalized well costs in excess of one year relates to the JDA in the Gulf of Thailand where hydrocarbons were encountered in three successful exploration wells drilled in the western part of Block A-18. The operator is currently evaluating well results and formulating future drilling plans in the area.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2016
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill	5. Goodwill The changes in the carrying amount of goodwill were as follows: Exploration and Production Bakken Midstream Total (In millions) Balance at January 1, 2015 $ 1,858 $ — $ 1,858 Reclassification (375 ) 375 — Impairment (1,483 ) — (1,483 ) Balance at December 31, 2015 — 375 375 Reclassification — — — Impairment — — — Balance at December 31, 2016 $ — $ 375 $ 375 In the second quarter of 2015, we established a new operating segment, the Bakken Midstream segment which had previously been reported as part of the Onshore reporting unit within the E&P operating segment. The E&P operating segment previously had two reporting units, Offshore which had allocated goodwill of $1,098 million and Onshore which had allocated goodwill of $760 million prior to forming the Bakken Midstream operating segment. Upon formation of the Bakken Midstream operating segment, we allocated $375 million of goodwill from the Onshore reporting unit to the Bakken Midstream operating segment based on the relative fair values of the Bakken Midstream business and the remainder of the Onshore reporting unit. There was no change to the composition of the Offshore reporting unit. See Note 6, Impairment

Impairment

Impairment	12 Months Ended
	Dec. 31, 2016
Asset Impairment Charges [Abstract]
Impairment	6. Impairment In 2016, we recorded a pre-tax impairment charge of $67 million ($21 million after income taxes and noncontrolling interest) to impair older specification rail cars in our Midstream segment based on estimated salvage values, which approximate fair value and represent a Level 3 fair value measurement as defined under accounting standards. In 2015, we recorded pre-tax goodwill impairment charges totaling $1,483 million ($1,483 million after income taxes). As a result of establishing the Bakken Midstream operating segment in the second quarter of 2015, (see Note 5, Goodwill As a result of the prevailing low crude oil price in 2015, we also recognized an impairment charge of $133 million pre-tax ($83 million after income taxes) relating to our legacy conventional North Dakota assets based on projected discounted cash flows, using similar Level 3 inputs to those discussed above.

Bakken Midstream Joint Venture

Bakken Midstream Joint Venture	12 Months Ended
	Dec. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Bakken Midstream Joint Venture	7. Bakken Midstream Joint Venture On July 1, 2015, we sold a 50% interest in HIP to Global Infrastructure Partners (GIP) for net cash consideration of approximately $2.6 billion. HIP and its affiliates primarily comprise our Bakken Midstream operating segment which provides fee-based services including crude oil and natural gas gathering, processing of natural gas and the fractionation of natural gas liquids, transportation of crude oil by rail car, terminaling and loading crude oil and natural gas liquids, and the storage and terminaling of propane, primarily in the Bakken shale play of North Dakota. The Bakken Midstream operating segment currently generates substantially all of its revenues under long-term, fee-based agreements with our E&P operating segment and intends to pursue additional throughput volumes from third parties in the Williston Basin area. We operate the Bakken Midstream assets and operations, including routine and emergency maintenance and repair services under various operational and administrative services agreements. The tariff agreements between our E&P operating segment and the Bakken Midstream entities became effective on January 1, 2014 and are 10-year, fee-based commercial agreements, with HIP having the sole option to renew the agreements for an additional 10-year term. These agreements include minimum volume commitments based on dedicated production, inflation escalators and fee recalculation mechanisms. The Bakken Midstream segment has minimal direct commodity price exposure, and the E&P segment retains ownership of the crude oil, natural gas or natural gas liquids processed, terminaled, stored or transported by the Bakken Midstream segment. We consolidate the activities of HIP, which qualifies as a variable interest entity (VIE) under U.S. generally accepted accounting principles. We have concluded that we are the primary beneficiary of the VIE, as defined in the accounting standards, since we have the power, through our 50% ownership, to direct those activities that most significantly impact the economic performance of HIP. This conclusion was based on a qualitative analysis that considered HIP’s governance structure, the commercial agreements between HIP and us, and the voting rights established between the members which provide us the ability to control the operations of HIP. As a result of the sale to GIP in 2015, we recorded an after-tax gain of $763 million in additional paid-in-capital and $1,298 million in noncontrolling interest representing GIP’s proportional share of our basis in the net assets of HIP. The results attributable to GIP’s 50% ownership are reported within Net income (loss) attributable to noncontrolling interests in the Statement of Consolidated Income Consolidated Balance Sheet Upon formation, the joint venture incurred $600 million of borrowings through a 5-year Term Loan A facility with the proceeds distributed equally to the partners. At December 31, 2016, HIP liabilities totaling $841 million (2015: $831 million) are on a nonrecourse basis to Hess Corporation, while HIP assets available to settle the obligations of HIP included Cash and cash equivalents totaling $2 million (2015: $3 million) and Property, plant and equipment totaling $2,528 million (2015: $2,358 million).

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2016
Disposition Of Businesses [Abstract]
Dispositions	8. Dispositions 2016: We sold miscellaneous non-core assets during the year for proceeds totaling approximately $100 million and recognized net pre-tax gains totaling $23 million ($14 million after income taxes). 2015: We sold approximately 13,000 acres of Utica dry gas acreage for a sale price of approximately $120 million. This transaction resulted in a pre-tax gain of $49 million ($31 million after income taxes). We also disposed of our interest in Algeria and recognized a pre-tax loss of $21 million ($21 million after income taxes) and sold land associated with our former joint venture interest in the Bayonne Energy Center for $20 million, resulting in a pre-tax gain of $20 million ($13 million after income taxes). 2014: We completed the sale of our interest in the Pangkah asset, offshore Indonesia for cash proceeds of approximately $650 million, which resulted in a pre-tax gain of $31 million ($10 million loss after income taxes). We also completed the sale of our interests in Thailand for cash proceeds of approximately $805 million, which resulted in a pre-tax gain of $706 million ($706 million after income taxes). In addition, we completed the sale of approximately 77,000 net acres in the dry gas area of the Utica shale play including related wells and facilities through multiple transactions, for cash proceeds of $1,075 million and recorded a pre-tax gain of $62 million ($35 million after income taxes). In June, we completed the sale of our 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, we sold our joint venture interest in Bayonne Energy Center for $79 million, which did not result in a gain or loss. Also in September, we completed the sale of our 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).

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations And Disposal Groups [Abstract]
Discontinued Operations	9. Discontinued Operations The results of operations for our divested Marketing and Refining businesses, which included ownership of the energy trading partnership through February 2015 and retail marketing through September 2014, have been reported as discontinued operations in the Statement of Consolidated Income Statement of Consolidated Cash Flows Sales and other operating revenues and income from discontinued operations were as follows: 2016 2015 2014 (In millions) Sales and other operating revenues $ — $ 14 $ 9,576 Income (Loss) from Discontinued Operations Before Income Taxes $ — $ (74 ) $ 1,071 Current tax provision (benefit) — — — Deferred tax provision (benefit) — (26 ) 389 Provision (benefit) for income taxes — (26 ) 389 Income (loss) from Discontinued Operations, Net of Income Taxes $ — $ (48 ) $ 682 Less: Net income (loss) attributable to noncontrolling interests — — 57 Income (Loss) from Discontinued Operations Attributable to Hess Corporation $ — $ (48 ) $ 625 2015: In February, we sold our interest in HETCO, which was subsequently renamed Hartree Partners, LP (Hartree). Pursuant to the terms of the sale, Hartree was permitted to utilize our guarantees issued in favor of Hartree's existing counterparties until November 12, 2015, provided that new trades were for a period of one year or less, complied with certain credit requirements, and net exposures remained within value at risk limits previously applied by us. The guarantees remain in effect until the qualifying trades outstanding at November 12, 2015 mature. We have the right to seek reimbursement from Hartree and a separate Hartree credit support facility upon any counterparty draw on the applicable guarantee from us. No draws on the guaranteed trades have occurred through December 31, 2016. 2014: In September, we completed the sale of our 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, we 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, we 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. We 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, our retail business acquired our 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, we recorded a pre-tax gain of $39 million ($24 million after income taxes) to remeasure the carrying value of our original 44% equity interest in WilcoHess to fair value, including recognition of goodwill in the amount of $115 million. The assets and liabilities acquired from WilcoHess were included in the sale of the retail business in September 2014.

HOVENSA LLC

HOVENSA LLC	12 Months Ended
	Dec. 31, 2016
Reorganizations [Abstract]
HOVENSA LLC	10. HOVENSA LLC HOVENSA LLC (HOVENSA), a 50/50 joint venture between the Corporation’s subsidiary, Hess Oil Virgin Islands Corp. (HOVIC), and Petroleos de Venezuela S.A. (PDVSA), had previously shut down its U.S. Virgin Islands refinery in 2012 and filed a voluntary petition for relief under Chapter 11 of the United States Bankruptcy Code in the United States District Court of the Virgin Islands in September 2015. To fund HOVENSA's sale process and orderly wind-down, HOVENSA entered into a $40 million debtor-in-possession credit facility with HOVENSA’s owners, the terms of which were approved by the Bankruptcy Court. On December 1, 2015, the Bankruptcy Court entered an order approving the sale of HOVENSA’s terminal and refinery assets to Limetree Bay Terminals, LLC (Limetree). The Senate of the U.S. Virgin Islands approved the sale on December 29, 2015, and the sale to Limetree was completed on January 4, 2016. On January 19, 2016, the Bankruptcy Court entered an order confirming HOVENSA’s Chapter 11 plan of liquidation (the “Liquidation Plan”). Under the Liquidation Plan, HOVENSA established a liquidating trust to distribute certain assets and sale proceeds to its creditors, established an environmental response trust to administer to HOVENSA’s remaining environmental obligations and to conduct an orderly wind-down of its remaining activities. The Liquidation Plan also provided for releases of any claims held by HOVENSA and its bankruptcy estate against us and HOVIC, which were effective on the effective date of the Liquidation Plan. In connection with the Liquidation Plan and HOVENSA’s asset sale, we relinquished our claims against HOVENSA to recover the 2012 and 2015 promissory notes issued by HOVENSA. In addition, we assumed the HOVENSA pension plan upon the effective date of the Liquidation Plan. In 2015, we recorded a charge of $30 million primarily representing the estimated net difference between the HOVENSA pension plan obligation and fair value of the plan assets.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	11. Asset Retirement Obligations The following table describes changes to our asset retirement obligations: 2016 2015 (In millions) Balance at January 1 $ 2,383 $ 2,723 Liabilities incurred 42 57 Liabilities settled or disposed of (196 ) (360 ) Accretion expense 117 126 Revisions of estimated liabilities (230 ) 92 Foreign currency translation 12 (255 ) Balance at December 31 2,128 2,383 Less: Current Obligations 216 225 Long-term Obligations at end of period $ 1,912 $ 2,158 The liabilities settled or disposed of related primarily to abandonment activities conducted at the Valhall field offshore Norway in 2016 and 2015, the Gulf of Mexico in 2016, and the U.K. North Sea in 2015. The revisions in 2016 primarily relate to the South Arne Field, offshore Denmark, as a result of a 20-year extension to the license that extends expiry to 2047. Other revisions in 2016 and 2015 reflect changes in the expected scope of operations and updates to service and equipment costs. The fair value of sinking fund deposits that are legally restricted for purposes of settling asset retirement obligations, which are included in non-current Other assets in the Consolidated Balance Sheet

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	12. Debt Long‑term debt at December 31 consisted of the following: 2016 2015 (In millions) Debt Excluding Bakken Midstream: Fixed-rate public notes: 1.3% due 2017 $ — $ 299 8.1% due 2019 349 996 3.5% due 2024 297 296 4.3% due 2027 989 — 7.9% due 2029 499 693 7.3% due 2031 679 744 7.1% due 2033 596 595 6.0% due 2040 740 739 5.6% due 2041 1,232 1,231 5.8% due 2047 493 — Total fixed-rate public notes 5,874 5,593 Financing obligations associated with floating production system 192 264 Fair value adjustments - interest rate hedging 7 31 Total Debt Excluding Bakken Midstream $ 6,073 $ 5,888 Debt Related to Bakken Midstream Bakken Midstream - term loan A facility $ 580 $ 594 Bakken Midstream - revolving credit facility 153 110 Total Debt Related to Bakken Midstream $ 733 $ 704 Total Long-Term Debt: Total debt (a) (b) $ 6,806 $ 6,592 Less: Current maturities of long-term debt 112 86 Total Long-Term Debt $ 6,694 $ 6,506 (a) At December 31, 2016 the fair value of total debt amounted to $7,548 million (2015: $6,515 million ). (b) The Debt refinancing transaction: In September 2016, Hess Corporation issued $1 billion of 4.30% senior notes, due in April 2027, and $500 million of 5.80% senior notes, due in April 2047 primarily to fund the repurchase of tendered higher-coupon debt and redemption of near-term maturities. We used proceeds of $1.38 billion to purchase or redeem $650 million principal amount of 8.125% notes due 2019, $196 million principal amount of 7.875% notes due 2029, $66 million principal amount of 7.30% notes due 2031 and $300 million principal amount of 1.30% notes due 2017. As a result of this debt refinancing transaction, we incurred a charge of $148 million for the loss on extinguishment of the tendered and redeemed notes. Debt excluding Bakken Midstream: At December 31, 2016, Hess Corporation’s fixed-rate public notes had a gross principal amount of $5,938 million (2015: $5,650 million) and a weighted average interest rate of 6.0% (2015: 6.4%). Our 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 us to borrow up to an additional $4,585 million of secured debt at December 31, 2016. In 2016, we capitalized $61 million of interest (2015: $45 million; 2014: $76 million). Hess Corporation has a $4 billion syndicated revolving credit facility that expires in January 2020. Borrowings on the facility will generally bear interest at 1.3% above the London Interbank Offered Rate (LIBOR). The interest rate will be higher if our credit rating is lowered. The facility contains a financial covenant that limits the amount of total borrowings on the last day of each fiscal quarter to 65% of the Corporation’s total capitalization, defined as total debt plus stockholders’ equity. At December 31, 2016, Hess Corporation had no outstanding borrowings or letters of credit issued against the syndicated revolving credit facility and was in compliance with this financial covenant. Letters of credit: Outstanding letters of credit at December 31 were as follows: 2016 2015 (In millions) Committed lines (a) $ 1 $ 10 Uncommitted lines (a) 187 103 Total (b) $ 188 $ 113 (a) At December 31, 2016, committed and uncommitted lines have expiration dates through 2018. (b) At December 31, 2016, $27 million relates to contingent liabilities and $161 million relates to liabilities recorded in the Consolidated Balance Sheet (2015: $32 million and $81 million, respectively). Debt related to Bakken Midstream: In July 2015, HIP, a 50/50 joint venture between us and GIP, incurred $600 million of debt through a 5-year Term Loan A facility. The proceeds from the debt were distributed equally to the partners. HIP also entered into a $400 million 5-year syndicated revolving credit facility, which can be used for borrowings and letters of credit, and is expected to fund the joint venture’s operating activities and capital expenditures. Borrowings on both loan facilities are non-recourse to Hess Corporation and generally bear interest at LIBOR plus an applicable margin ranging from 1.10% to 2.00%. The interest rate is subject to adjustment based on the joint venture’s leverage ratio, which is calculated as total debt to Earnings Before Interest, Taxes, Depreciation and Amortization (EBITDA). If the joint venture obtains credit ratings, pricing levels will be based on its credit ratings in effect from time to time. The joint venture is subject to customary covenants in the credit agreement, including financial covenants that generally require a leverage ratio of no more than 5.0 to 1.0 for the prior four fiscal quarters and an interest coverage ratio, which is calculated as EBITDA to interest expense, of no less than 2.25 to 1.0 for the prior four fiscal quarters. HIP is in compliance with all debt covenants at December 31, 2016, and its financial covenants do not currently impact their ability to issue indebtedness to fund future capital expenditures.

Share-based Compensation

Share-based Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-based Compensation	13. Share-based Compensation We have established and maintain a Long-term Incentive Plan (LTIP), as amended, for the granting of restricted common shares, performance share units (PSUs) and stock options to our employees. As of December 31, 2016, the total number of authorized common stock under LTIP, as amended, was 38.0 million shares, of which we have 10.6 million shares available for issuance. Outstanding restricted stock and PSUs generally vest three years from the date of grant. Restricted common shares are valued based on the prevailing market price of our common stock on 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: 2016 2015 2014 (In millions) Restricted stock $ 45 $ 67 $ 62 Stock options 7 5 2 Performance share units 21 25 19 Share-based compensation expense before income taxes (a) $ 73 $ 97 $ 83 Income tax benefit on share-based compensation expense $ 28 $ 36 $ 31 (a) Based on share‑based compensation awards outstanding at December 31, 2016, unearned compensation expense, before income taxes, will be recognized in future years as follows (in millions): 2017—$66, 2018—$35, and 2019—$6. Share‑based compensation activity consisted of the following: Performance Share Units Stock Options Restricted Stock Performance Share Units Weighted - Average Fair Value on Date of Grant Options Weighted - Average Exercise Price per Share Shares of Restricted Common Stock Weighted - Average Price on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2016 820 $ 89.43 6,911 $ 67.77 2,820 $ 75.32 Granted 447 50.94 824 44.60 1,661 44.69 Exercised — — (227 ) 53.43 — — Vested (193 ) 111.49 — — (833 ) 69.57 Forfeited (59 ) 65.11 (916 ) 55.00 (547 ) 66.98 Outstanding at December 31, 2016 1,015 $ 69.68 6,592 $ 67.15 3,101 $ 61.93 As of December 31, 2016, there were 6.6 million outstanding stock options (5.5 million exercisable) with a weighted average remaining contractual life of 3.6 years (2.6 years for exercisable options) and an aggregated intrinsic value of $27 million ($14 million for exercisable options). The weighted average exercise price for options exercisable at December 31, 2016 was $69.71 per share. The following weighted average assumptions were utilized to estimate the fair value of stock options: 2016 2015 2014 Risk free interest rate 1.47 % 1.77 % 1.86 % Stock price volatility 0.326 0.312 0.363 Dividend yield 2.26 % 1.34 % 1.24 % Expected life in years 6.0 6.0 6.0 Weighted average fair value per option granted $ 11.33 $ 21.00 $ 26.46 The following weighted average assumptions were utilized to estimate the fair value of PSU awards: 2016 2015 2014 Risk free interest rate 0.96 % 1.02 % 0.65 % Stock price volatility 0.329 0.270 0.359 Contractual term in years 3.0 3.0 3.0 Grant date price of Hess common stock $ 44.31 $ 74.49 $ 80.35 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.

Retirement Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2016
Compensation And Retirement Disclosure [Abstract]
Retirement Plans	14. Retirement Plans We have funded noncontributory defined benefit pension plans for a significant portion of our employees. In addition, we have an unfunded supplemental pension plan covering certain employees, which provides incremental payments that would have been payable from our 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, we maintain 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 benefit obligations, the fair value of plan assets, and the funded status of our pension and postretirement medical plans: Funded Unfunded Postretirement Pension Plans Pension Plan Medical Plan 2016 2015 2016 2015 2016 2015 (In millions) Change In Benefit Obligation Balance at January 1 $ 2,321 $ 2,450 $ 259 $ 278 $ 98 $ 94 Service cost 44 51 16 16 4 4 Interest cost 98 93 9 9 3 3 Actuarial loss (gain) (a) 162 (156 ) (5 ) (2 ) (13 ) 5 Benefit payments (b) (132 ) (85 ) (23 ) (42 ) (8 ) (8 ) Plan curtailments (2 ) (4 ) — — — — Special termination benefits 1 1 — — — — Assumption of HOVENSA pension plan 151 — — — — — Foreign currency exchange rate changes (83 ) (29 ) — — — — Balance at December 31 2,560 2,321 256 259 84 98 Change In Fair Value of Plan Assets Balance at January 1 $ 2,206 $ 2,251 $ — $ — $ — $ — Actual return on plan assets 153 28 — — — — Employer contributions 26 44 23 42 8 8 Benefit payments (b) (132 ) (85 ) (23 ) (42 ) (8 ) (8 ) Assumption of HOVENSA pension plan 126 — — — — — Foreign currency exchange rate changes (95 ) (32 ) — — — — Balance at December 31 2,284 2,206 — — — — Funded Status (Plan assets greater (less) than benefit obligations) at December 31 $ (276 ) $ (115 ) $ (256 ) $ (259 ) $ (84 ) $ (98 ) Unrecognized Net Actuarial (Gains) Losses $ 895 $ 775 $ 93 $ 105 $ (13 ) $ — (a) The change in discount rate in 2016 resulted in total actuarial losses of approximately $175 million. (b) Benefit payments include lump-sum settlement payments of $65 million in 2016 (2015: $41 million). Amounts recognized in the Consolidated Balance Sheet at December 31 consisted of the following: Funded Unfunded Postretirement Pension Plans Pension Plan Medical Plan 2016 2015 2016 2015 2016 2015 (In millions) Pension asset / (accrued benefit liability) $ (276 ) $ (115 ) $ (256 ) $ (259 ) $ (84 ) $ (98 ) Accumulated other comprehensive loss, pre-tax (a) 895 775 93 105 (13 ) — (a) The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $660 million at December 31, 2016 (2015: $563 million deficit). At December 31, 2016, the accumulated benefit obligation for the funded and unfunded defined benefit pension plans was $2,471 million and $203 million, respectively (2015: $2,223 million and $196 million, respectively). The net periodic benefit cost for funded and unfunded pension plans, and the postretirement medical plan, is as follows: Pension Plans Postretirement Medical Plan 2016 2015 2014 2016 2015 2014 (In millions) Service cost $ 60 $ 67 $ 57 $ 4 $ 4 $ 4 Interest cost 107 102 100 3 3 3 Expected return on plan assets (166 ) (168 ) (161 ) — — — Amortization of unrecognized net actuarial losses 60 75 32 — — — Settlement loss — 17 24 — — — Special termination benefit recognized 1 1 1 — — — Net Periodic Benefit Cost $ 62 $ 94 $ 53 $ 7 $ 7 $ 7 For 2017, the pension and postretirement medical expense is estimated to be approximately $61 million, which includes approximately $67 million related to the amortization of unrecognized net actuarial losses. The weighted average actuarial assumptions used for funded and unfunded pension plans were as follows: 2016 2015 2014 Weighted Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.7 % 4.1 % 3.8 % Rate of compensation increase 4.6 % 4.5 % 5.0 % Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31 Discount rate 4.1 % 3.8 % 4.6 % Expected return on plan assets 7.4 % 7.5 % 7.5 % Rate of compensation increase 4.5 % 5.0 % 4.4 % The actuarial assumptions used for postretirement medical plan, as follows: 2016 2015 2014 Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.5 % 3.5 % 3.1 % Initial health care trend rate 7.7 % 6.7 % 6.8 % Ultimate trend rate 4.5 % 4.5 % 4.5 % Year in which ultimate trend rate is reached 2038 2038 2029 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. Our 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 our 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, 2016 and 2015 in accordance with the fair value measurement hierarchy described in Note 1, Nature of Operations, Basis of Presentation and Summary of Accounting Policies Level 1 Level 2 Level 3 Total (In millions) December 31, 2016 Cash and Short-Term Investment Funds $ 9 $ 79 $ — $ 88 Equities: U.S. equities (domestic) 550 — — 550 International equities (non-U.S.) 160 275 — 435 Global equities (domestic and non-U.S.) 2 197 — 199 Fixed Income: Treasury and government issued (a) — 202 — 202 Government related (b) — 38 — 38 Mortgage-backed securities (c) — 164 2 166 Corporate 1 186 — 187 Other: Hedge funds — — 209 209 Private equity funds — — 126 126 Real estate funds 10 — 52 62 Diversified commodities funds — 22 — 22 $ 732 $ 1,163 $ 389 $ 2,284 December 31, 2015 Cash and Short-Term Investment Funds $ — $ 34 $ — $ 34 Equities: U.S. equities (domestic) 556 — — 556 International equities (non-U.S.) 159 266 — 425 Global equities (domestic and non-U.S.) 2 217 — 219 Fixed Income: Treasury and government issued (a) — 213 — 213 Government related (b) — 6 1 7 Mortgage-backed securities (c) — 174 2 176 Corporate — 157 — 157 Other: Hedge funds — — 216 216 Private equity funds — — 122 122 Real estate funds 12 — 52 64 Diversified commodities funds — 17 — 17 $ 729 $ 1,084 $ 393 $ 2,206 (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, 2015 $ 2 $ 302 $ 105 $ 48 $ 457 Actual return on plan assets — (5 ) 18 9 22 Purchases, sales or other settlements 1 (81 ) (1 ) (5 ) (86 ) Net transfers in (out) of Level 3 — — — — — Balance at December 31, 2015 3 216 122 52 393 Actual return on plan assets — (7 ) 5 7 5 Purchases, sales or other settlements (1 ) — (1 ) (7 ) (9 ) Net transfers in (out) of Level 3 — — — — — Balance at December 31, 2016 $ 2 $ 209 $ 126 $ 52 $ 389 We expect to contribute approximately $52 million to our funded pension plans in 2017. 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): 2017 $ 138 2018 123 2019 133 2020 135 2021 136 Years 2022 to 2026 725 We also have several defined contribution plans for certain eligible employees. Employees may contribute a portion of their compensation to these plans and we match a portion of the employee contributions. We recorded expense of $25 million in 2016 for contributions to these plans (2015: $28 million; 2014: $32 million).

Exit and Disposal Costs

Exit and Disposal Costs	12 Months Ended
	Dec. 31, 2016
Restructuring And Related Activities [Abstract]
Exit and Disposal Costs	15. Exit and Disposal Costs In 2016, we incurred severance expense of $55 million (2015: $13 million; 2014: $76 million) and paid accrued severance costs of $52 million (2015: $57 million; 2014: $170 million). The severance charge in 2016 primarily resulted from a in November 2016. At December 31, 2016, we had accrued liabilities for severance costs of $36 million (2015: $33 million) and accrued liabilities for exit costs of $17 million (2015: $19 million). Of the accrued liabilities at December 31, 2016, all severance costs are expected to be paid in 2017 and the exit costs of $14 million will be paid over the next several years.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	16. Income Taxes The provision (benefit) for income taxes from continuing operations consisted of: 2016 2015 2014 (In millions) United States Federal Current $ (27 ) $ (7 ) $ (1 ) Deferred taxes and other accruals 1,948 (995 ) 156 State 23 (61 ) 57 1,944 (1,063 ) 212 Foreign Current 36 4 453 Deferred taxes and other accruals 235 (231 ) 79 271 (227 ) 532 Total 2,215 (1,290 ) 744 Adjustment of deferred taxes for foreign income tax law changes 7 (9 ) — Total Provision (Benefit) For Income Taxes (a) $ 2,222 $ (1,299 ) $ 744 (a) Includes charges of $3,749 million in 2016 to establish valuation allowances on net deferred tax assets which is discussed further below. Income (loss) from continuing operations before income taxes consisted of the following: 2016 2015 2014 (In millions) United States (a) $ (2,431 ) $ (2,728 ) $ 676 Foreign (1,423 ) (1,530 ) 1,760 Total Income (Loss) from Continuing Operations Before Income Taxes $ (3,854 ) $ (4,258 ) $ 2,436 (a) Includes substantially all of our 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: 2016 2015 (In millions) Deferred Tax Liabilities Property, plant and equipment and investments $ (3,810 ) $ (3,743 ) Other (255 ) (257 ) Total Deferred Tax Liabilities (4,065 ) (4,000 ) Deferred Tax Assets Net operating loss carryforwards 5,767 3,852 Tax credit carryforwards 164 188 Property, plant and equipment and investments 834 981 Accrued compensation, deferred credits and other liabilities 526 492 Asset retirement obligations 1,077 1,220 Other 62 165 Total Deferred Tax Assets 8,430 6,898 Valuation allowances (5,450 ) (1,579 ) Total deferred tax assets, net of valuation allowances 2,980 5,319 Net Deferred Tax Assets (Liabilities) $ (1,085 ) $ 1,319 At December 31, 2016, we have recognized a gross deferred tax asset related to net operating loss carryforwards of $5,767 million before application of valuation allowances. The deferred tax asset is comprised of $2,610 million attributable to foreign net operating losses which begin to expire in 2024, $2,766 million attributable to U.S. federal operating losses which begin to expire in 2021 and $391 million attributable to losses in various U.S. states which began to expire in 2017. The deferred tax asset attributable to foreign net operating losses, net of valuation allowances, is As of December 31, 2016, the Balance Sheet reflects a $5,450 million valuation allowance against the net deferred tax assets for multiple jurisdictions based on application of the relevant accounting standards, with $3,749 million recorded in the fourth quarter of 2016 related primarily to the U.S., Denmark (hydrocarbon tax only), and Malaysia. The charge in 2016 is comprised of net deferred tax assets as of the beginning of the year totaling $2,683 million and additional net deferred tax assets recognized during the year of $1,066 million. Management assesses the available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. The cumulative loss incurred over the three-year period ending December 31, 2016 constitutes significant objective negative evidence. Such objective negative evidence limits our ability to consider subjective positive evidence, such as our projections of future taxable income, resulting in the recognition of a valuation allowance against the net deferred tax assets for these jurisdictions. The amount of the deferred tax asset considered realizable, however, could be adjusted if estimates of future taxable income change or if objective negative evidence in the form of cumulative losses is no longer present and additional weight can be given to subjective evidence. In the Consolidated Balance Sheet 2016 2015 (In millions) Deferred income taxes (long-term asset) $ 59 $ 2,653 Deferred income taxes (long-term liability) (1,144 ) (1,334 ) Net Deferred Tax Assets (Liabilities) $ (1,085 ) $ 1,319 The difference between our effective income tax rate from continuing operations and the U.S. statutory rate is reconciled below: 2016 2015 2014 U.S. statutory rate 35.0 % 35.0 % 35.0 % Effect of foreign operations (a) 4.6 5.9 0.7 State income taxes, net of Federal income tax 1.9 0.9 1.5 Change in enacted tax laws (0.2 ) 0.2 — Gains on asset sales, net — (0.2 ) (8.3 ) Impairment (2.1 ) (12.2 ) — Valuation allowance against previously benefitted deferred tax assets (97.3 ) (3.1 ) 0.6 Benefit of legal entity restructuring — 3.5 — Other 0.4 0.5 1.0 Total (57.7 ) % 30.5 % 30.5 % (a) The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the mix of income among high and low tax rate jurisdictions. Below is a reconciliation of the gross beginning and ending amounts of unrecognized tax benefits: 2016 2015 (In millions) Balance at January 1 $ 604 $ 603 Additions based on tax positions taken in the current year 19 19 Additions based on tax positions of prior years 113 29 Reductions based on tax positions of prior years (274) (31) Reductions due to settlements with taxing authorities (27) (12) Reductions due to lapses in statutes of limitation (11) (4) Balance at December 31 $ 424 $ 604 The December 31, 2016 balance of unrecognized tax benefits includes $233 million that, if recognized, would impact our effective income tax rate. Over the next 12 months, it is reasonably possible that the total amount of unrecognized tax benefits could decrease by approximately $85 million due to settlements with taxing authorities or other resolutions, as well as lapses in statutes of limitation. At December 31, 2016, our accrued interest and penalties related to unrecognized tax benefits is $29 million (2015: $74 million). We have not recognized deferred income taxes on the portion of undistributed earnings of foreign subsidiaries expected to be indefinitely reinvested in foreign operations. At December 31, 2016, we have undistributed earnings from foreign subsidiaries, which we expect to be indefinitely reinvested in foreign operations, of approximately $7.6 billion. We have not measured the unrecognized deferred tax liability related to these earnings because this determination is not practicable. We file income tax returns in the U.S. and various foreign jurisdictions. We are no longer subject to examinations by income tax authorities in most jurisdictions for years prior to 2005.

Outstanding and Weighted Averag

Outstanding and Weighted Average Common Shares	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Outstanding and Weighted Average Common Shares	17. Outstanding and Weighted Average Common Shares The following table provides the changes in our outstanding common shares: 2016 2015 2014 (In millions) Balance at January 1 286.0 285.8 325.3 Shares issued 28.8 — — Activity related to restricted stock awards, net 1.1 0.8 0.6 Stock options exercised 0.2 0.2 3.3 PSU vested 0.4 0.6 — Shares repurchased (a) — (1.4 ) (43.4 ) Balance at December 31 316.5 286.0 285.8 (a) See Note 18, Share Repurchase Plan. The following table presents the calculation of basic and diluted earnings per share: 2016 2015 2014 (In millions, except per share amounts) Net Income (Loss) Attributable to Hess Corporation Common Stockholders: Income (loss) from continuing operations, net of income taxes $ (6,076 ) $ (2,959 ) $ 1,692 Less: Net income (loss) attributable to noncontrolling interests 56 49 — Net income (loss) from continuing operations attributable to Hess Corporation (6,132 ) (3,008 ) 1,692 Less: Preferred stock dividends 41 — — Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders (6,173 ) (3,008 ) 1,692 Income (loss) from discontinued operations, net of income taxes — (48 ) 682 Less: Net income (loss) attributable to noncontrolling interests — — 57 Net income (loss) from discontinued operations attributable to Hess Corporation — (48 ) 625 Net income (loss) attributable to Hess Corporation Common Stockholders $ (6,173 ) $ (3,056 ) $ 2,317 Weighted Average Number of Common Shares Outstanding: Basic 309.9 283.6 303.7 Effect of dilutive securities Restricted common stock — — 1.5 Stock options — — 1.8 Performance share units — — 0.7 Mandatory Convertible Preferred stock — — — Diluted 309.9 283.6 307.7 Net Income (Loss) Attributable to Hess Corporation per Common Share: Basic: Continuing operations $ (19.92 ) $ (10.61 ) $ 5.57 Discontinued operations — (0.17 ) 2.06 Net income (loss) per common share $ (19.92 ) $ (10.78 ) $ 7.63 Diluted: Continuing operations $ (19.92 ) $ (10.61 ) $ 5.50 Discontinued operations — (0.17 ) 2.03 Net income (loss) per common share $ (19.92 ) $ (10.78 ) $ 7.53 The following table summarizes the number of antidilutive shares excluded from the computation of diluted shares: 2016 2015 2014 (In millions) Restricted common stock 3.3 2.9 — Stock options 6.9 6.9 1.4 Performance share units 0.9 1.0 — Common shares from conversion of preferred stock 11.2 — — In 2016, 2015 and 2014, cash dividends declared on common stock totaled $1.00 per share ($0.25 per quarter).

Share Repurchase Plan

Share Repurchase Plan	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Share Repurchase Plan	18. Share Repurchase Plan In 2013, our Board of Directors authorized the repurchase of up to $4.0 billion in aggregate purchase price of our common stock. In May 2014, the Board of Directors approved an increase in the program to $6.5 billion. Repurchases under this program to date have been as follows: 2016 2015 2014 To Date (In millions) Total cost of shares repurchased $ — $ 91 $ 3,722 $ 5,351 Total number of shares repurchased — 1.45 43.35 64.11 As of December 31, 2016, we are authorized, but not required, to purchase additional common stock up to a value of $1.15 billion.

Supplementary Cash Flow Informa

Supplementary Cash Flow Information	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Supplementary Cash Flow Information	19. Supplementary Cash Flow Information The following information supplements the Statement of Consolidated Cash Flows 2016 2015 2014 (In millions) Cash Flows From Operating Activities Interest paid $ (338 ) $ (331 ) $ (326 ) Net income taxes (paid) refunded 132 (140 ) (455 ) Cash Flows From Investing Activities Capital expenditures incurred - E&P (1,645 ) (3,753 ) (4,920 ) Increase (decrease) in related liabilities (334 ) (203 ) 53 Additions to property, plant and equipment - E&P (1,979 ) (3,956 ) (4,867 ) Capital expenditures incurred - Bakken Midstream (276 ) (296 ) (301 ) Increase (decrease) in related liabilities 4 (69 ) (46 ) Additions to property, plant and equipment - Bakken Midstream (272 ) (365 ) (347 ) Cash Flows From Financing Activities Contribution from formation of Bakken Midstream joint venture — 2,628 — Distributions to partner in Bakken Midstream joint venture (23 ) (332 ) — Noncontrolling interests, net related to Continuing operations (23 ) 2,296 — Significant Non-Cash Transactions Increase in debt due to construction of a floating production system - Tubular Bells Field $ — $ — $ 68

Leased Assets

Leased Assets	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Leased Assets	20. Leased Assets We and certain of our subsidiaries lease drilling rigs, 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, 2016, 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): 2017 $ 376 2018 375 2019 351 2020 124 2021 67 Remaining years 338 Total Minimum Lease Payments 1,631 Less: Income from subleases 78 Net Minimum Lease Payments $ 1,553 Rental expense was as follows: 2016 2015 2014 (In millions) Total rental expense $ 106 $ 167 $ 248 Less: Income from subleases 5 10 17 Net Rental Expense $ 101 $ 157 $ 231

Guarantees, Contingencies and C

Guarantees, Contingencies and Commitments	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Guarantees, Contingencies and Commitments	21. Guarantees, Contingencies and Commitments Guarantees and Contingencies At December 31, 2016, we have $27 million in letters of credit for which we are contingently liable. In addition, we are subject to loss contingencies with respect to various claims, lawsuits and other proceedings. A liability is recognized in our 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, we disclose the nature of those contingencies. We cannot predict with certainty if, how or when existing claims, lawsuits and proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages. 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, including the matters described below, is not expected to have a material adverse effect on our financial condition. However, we could incur judgments, enter into settlements or revise our opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations in the period in which the amounts are accrued and our cash flows in the period in which the amounts are paid. We, along with many companies that have been or continue to be engaged in refining and marketing of gasoline, have 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 us. 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 us have been settled. In June 2014, the Commonwealth of Pennsylvania and the State of Vermont each filed independent lawsuits alleging that we 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. In September 2016, the State of Rhode Island also filed a lawsuit in Federal court alleging that we and other major oil companies damaged the groundwater in Rhode Island by introducing thereto gasoline with MTBE. In September 2003, we received a directive from the New Jersey Department of Environmental Protection (NJDEP) to remediate contamination in the sediments of the Lower Passaic River. The NJDEP is also seeking natural resource damages. The directive, insofar as it affects us, relates to alleged releases from a petroleum bulk storage terminal in Newark, New Jersey we previously owned. We and over 70 companies entered into an Administrative Order on Consent with the Environmental Protection Agency (EPA) to study the same contamination; this work remains ongoing. We and other parties settled a cost recovery claim by the State of New Jersey and also agreed with EPA to fund remediation of a portion of the site. In April 2014, the EPA issued a Focused Feasibility Study (FFS) proposing to conduct bank-to-bank dredging of the lower eight miles of the Lower Passaic River at an estimated cost of $1.7 billion. On March 4, 2016, the EPA issued a Record of Decision (ROD) in respect of the lower eight miles of the Lower Passaic River, selecting a remedy that includes bank-to-bank dredging at an estimated cost of $1.38 billion. In March 2014, we received an Administrative Order from EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York. The remedy includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap. EPA has estimated that this remedy will cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain. Our alleged liability derives from our former ownership and operation of a fuel oil terminal adjacent to the Canal. We indicated to EPA that we would comply with the Administrative Order and are currently contributing funding for the Remedial Design based on an interim allocation of costs among the parties. At the same time, we are participating in an allocation process whereby neutral experts selected by the parties will determine the final shares of the Remedial Design costs to be paid by each of the participants. The parties have not yet addressed the allocation of costs associated with implementing the remedy that is currently being designed. On January 18, 2017, we entered into a Consent Decree with the North Dakota Department of Health resolving alleged non-compliance with North Dakota’s air pollution laws and provisions of the federal Clean Air Act. Pursuant to the Consent Decree, we are required to implement corrective actions, including implementation of a leak detection and repair program, at most of our existing facilities in North Dakota. We were assessed a base penalty of $922,000, which is subject to adjustment based on the date we complete corrective actions required under the terms of the Consent Decree. We made an initial penalty payment of $55,000 during the first quarter of 2017. From time to time, we are involved in other judicial and administrative proceedings, including proceedings relating to other environmental matters. We cannot predict with certainty if, how or when such proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages. Numerous issues may need to be resolved, including through potentially lengthy discovery and determination of important factual matters before a loss or range of loss can be reasonably estimated for any proceeding. Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of such proceedings is not expected to have a material adverse effect on our financial condition, results of operations or cash flows. Unconditional Purchase Obligations and Commitments The following table shows aggregate information for certain unconditional purchase obligations and commitments at December 31, 2016 which are not included elsewhere within these Consolidated Financial Statements Payments Due by Period 2018 and 2020 and Total 2017 2019 2021 Thereafter (In millions) Capital expenditures $ 708 $ 632 $ 76 $ — $ — Operating expenses 497 393 76 18 10 Transportation and related contracts 1,560 182 457 433 488

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Information	22. Segment Information We currently have two operating segments, Exploration and Production and Bakken Midstream. The Exploration and Production operating segment explores for, develops, produces, purchases and sells crude oil, natural gas liquids and natural gas with production operations primarily in the United States (U.S.), Denmark, Equatorial Guinea, the JDA, Malaysia, and Norway. The Bakken Midstream operating segment provides fee-based services including crude oil and natural gas gathering, processing of natural gas and the fractionation of natural gas liquids, transportation of crude oil by rail car, terminaling and loading crude oil and natural gas liquids, and the storage and terminaling of propane, primarily in the Bakken shale play of North Dakota. All unallocated costs are reflected under Corporate, Interest and Other. The following table presents operating segment financial data for continuing operations (in millions): 2016 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 4,762 $ — $ — $ — $ 4,762 Intersegment Revenues — 510 — (510 ) — Operating Revenues $ 4,762 $ 510 $ — $ (510 ) $ 4,762 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ (4,963 ) $ 41 $ (1,210 ) $ — $ (6,132 ) Interest Expense — 19 319 — 338 Depreciation, Depletion and Amortization 3,132 102 10 — 3,244 Impairment — 67 — — 67 Provision (Benefit) for Income Taxes 1,588 25 609 — 2,222 Investment in Affiliates 146 — — — 146 Identifiable Assets 23,102 2,919 2,600 — 28,621 Capital Expenditures 1,645 276 — — 1,921 2015 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 6,636 $ — $ — $ — $ 6,636 Intersegment Revenues — 564 — (564 ) — Operating Revenues $ 6,636 $ 564 $ — $ (564 ) $ 6,636 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ (2,717 ) $ 86 $ (377 ) $ — $ (3,008 ) Interest Expense — 10 331 — 341 Depreciation, Depletion and Amortization 3,852 88 15 — 3,955 Impairment 1,616 — — — 1,616 Provision (Benefit) for Income Taxes (1,111 ) 52 (240 ) — (1,299 ) Investment in Affiliates 154 — — — 154 Identifiable Assets 28,863 2,754 2,540 — 34,157 Capital Expenditures 3,753 296 — — 4,049 2014 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 10,737 $ — $ — $ — $ 10,737 Intersegment Revenues — 319 — (319 ) — Operating Revenues $ 10,737 $ 319 $ — $ (319 ) $ 10,737 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ 2,086 $ 10 $ (404 ) $ — $ 1,692 Interest Expense — 2 321 — 323 Depreciation, Depletion and Amortization 3,140 70 14 — 3,224 Provision (Benefit) for Income Taxes 989 7 (252 ) — 744 Capital Expenditures 4,920 301 53 — 5,274 The following table presents financial information by major geographic area: United States Europe Africa Asia and Other Countries Corporate, Interest and other Total (In millions) 2016 Operating revenues $ 3,085 $ 610 $ 601 $ 466 $ — $ 4,762 Net income (loss) from continuing operations attributable to Hess Corporation (2,353 ) (439 ) (355 ) (1,775 ) (1,210 ) (6,132 ) Depreciation, depletion and amortization 2,133 502 375 224 10 3,244 Impairment 67 — — — — 67 Provision (benefit) for income taxes 411 243 244 715 609 2,222 Identifiable assets 16,096 5,180 1,507 3,238 2,600 28,621 Property, plant and equipment (net) (a) 14,596 4, 907 1,266 2,779 47 23,595 Capital expenditures 1,400 59 10 452 — 1,921 2015 Operating revenues $ 4,150 $ 870 $ 945 $ 671 $ — $ 6,636 Net income (loss) from continuing operations attributable to Hess Corporation (1,834 ) (408 ) (274 ) (115 ) (377 ) (3,008 ) Depreciation, depletion and amortization 2,449 635 539 317 15 3,955 Impairment 986 279 100 251 — 1,616 Provision (benefit) for income taxes (522 ) (84 ) (48 ) (405 ) (240 ) (1,299 ) Identifiable assets 18,365 6,207 2,178 4,867 2,540 34,157 Property, plant and equipment (net) (a) 15,729 5,300 1,682 3,520 121 26,352 Capital expenditures 2,727 297 160 865 — 4,049 2014 Operating revenues $ 6,270 $ 1,557 $ 2,002 $ 908 $ — $ 10,737 Net income (loss) from continuing operations attributable to Hess Corporation 654 226 545 671 (404 ) 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 Capital expenditures 3,467 524 399 831 53 5,274 (a) Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	23. Related Party Transactions The following table presents our related party transactions: 2016 2015 2014 (In millions) Sales: WilcoHess (a) $ — $ — $ 211 HOVENSA — — 31 (a) We acquired our partners’ 56% interest in WilcoHess in January 2014 for approximately $290 million. See Note 9, Discontinued Operations.

Financial Risk Management Activ

Financial Risk Management Activities	12 Months Ended
	Dec. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Financial Risk Management Activities	24. Financial Risk Management Activities In the normal course of our business, we are 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 financial risk management activities refer to the mitigation of these risks through hedging activities. We maintain a control environment for all of our financial risk management under the direction of our Chief Risk Officer. Our Treasury department is responsible for administering foreign exchange rate and interest rate hedging programs using similar controls and processes, where applicable. Hedging strategies are reviewed annually by the Audit Committee of the Board of Directors. 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 we produced or by reducing our 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 our crude oil or natural gas production. Forward contracts may also be used to purchase certain currencies in which we conduct the 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. 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. The gross notional amounts of financial risk management derivative contracts outstanding at December 31, were as follows: 2016 2015 (In millions of USD) Foreign exchange $ 785 $ 967 Interest rate swaps 350 1,300 The table below reflects the gross and net fair values of the risk management derivative instruments, all of which are based on Level 2 inputs: Accounts Receivable Accounts Payable (In millions) December 31, 2016 Derivative Contracts Designated as Hedging Instruments Interest rate $ — $ — Total derivative contracts designated as hedging instruments — — Derivative Contracts Not Designated as Hedging Instruments Foreign exchange 9 (1 ) Total derivative contracts not designated as hedging instruments 9 (1 ) Gross fair value of derivative contracts 9 (1 ) Master netting arrangements (1 ) 1 Net Fair Value of Derivative Contracts $ 8 $ — December 31, 2015 Derivative Contracts Designated as Hedging Instruments Interest rate $ 3 $ — Total derivative contracts designated as hedging instruments 3 — Derivative Contracts Not Designated as Hedging Instruments Foreign exchange 19 (3 ) Total derivative contracts not designated as hedging instruments 19 (3 ) Gross fair value of derivative contracts 22 (3 ) Master netting arrangements (3 ) 3 Net Fair Value of Derivative Contracts $ 19 $ — Derivative contracts designated as hedging instruments: Commodity: In 2015, c rude oil price hedging contracts increased E&P Sales and other operating revenues by $126 million, including losses of $48 million associated with changes in the time value of crude oil collars . In 2014, c rude oil price hedging contracts increased E&P Sales and other operating revenues by $193 million. There were no crude oil hedge contracts in 2016. Interest rate swaps: At December 31, 2016, we had interest rate swaps with gross notional amounts of $350 million (2015: $1,300 million), which were designated as fair value hedges. During 2016, we settled existing interest rate swaps and received cash proceeds of $5 million (2015: $41 million) . Changes in the fair value of interest rate swaps and the hedged fixed‑rate debt are recorded in Interest expense in the . In 2016, we recorded an increase of $6 million, excluding accrued interest, in the fair value of interest rate swaps and a corresponding adjustment in the carrying value of the hedged fixed‑rate debt (2015: $4 million increase; 2014: $1 million increase). Derivative contracts not designated as hedging instruments: Foreign exchange : Total foreign exchange gains and losses were a gain of $26 million in 2016 (2015: loss of $21 million; 2014: loss of $43 million) and are reported in Other, net in Revenues and non-operating income in the A component of foreign exchange gains or losses is the result of foreign exchange derivative contracts that are not designated as hedges which amounted to a gain of $62 million in 2016 (2015: gain of $98 million; 2014: gain of $117 million). The after‑tax foreign currency translation adjustments included in the Statement of Consolidated Comprehensive Income Credit Risk: We are 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, 2016, our Accounts receivable—Trade were concentrated with the following counterparty industry segments: Integrated companies — 37%, Independent E&P companies — 19%, National oil companies — 16%, Storage and transportation companies — 10%, Refining and marketing companies — 7% and Others — 11%. We reduce risk related to certain counterparties, where applicable, by using master netting arrangements and requiring collateral, generally cash or letters of credit. At December 31, 2016, we had outstanding letters of credit totaling $188 million (2015: $113 million). Fair Value Measurement: We have other short-term financial instruments, primarily cash equivalents, accounts receivable and accounts payable, for which the carrying value approximated fair value at December 31, 2016 and December 31, 2015. In addition, the disclosure for fair value of long-term debt in Note 12, Debt was based on Level 2 inputs.

Valuation and Qualifying Accoun

Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
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, 2016, 2015 and 2014 Additions Description Balance Charged to Charged to Deductions Balance (In millions) 2016 Losses on receivables $ 43 $ 5 $ — $ 40 $ 8 Deferred income tax valuation $ 1,578 $ 3,962 $ — $ 90 $ 5,450 2015 Losses on receivables $ 13 $ 32 $ — $ 2 $ 43 Deferred income tax valuation $ 1,416 $ 280 $ — $ 118 $ 1,578 2014 Losses on receivables $ 27 $ — $ — $ 14 $ 13 Deferred income tax valuation $ 1,519 $ 142 $ (1 ) $ 244 $ 1,416

Nature of Operations, Basis o33

Nature of Operations, Basis of Presentation and Summary of Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Basis of Presentation and Principles of Consolidation	Basis of Presentation and Principles of Consolidation: The consolidated financial statements include the accounts of Hess Corporation and entities in which we own more than a 50% voting interest. We also consolidate Hess Infrastructure Partners LP (HIP), a variable interest entity, based on our conclusion that we have the power through our 50% ownership to direct those activities that most significantly impact the economic performance of HIP, and are obligated to absorb losses or have the right to receive benefits that could potentially be significant to HIP. Our undivided interests in unincorporated oil and gas exploration and production ventures are proportionately consolidated. Investments in affiliated companies, 20% to 50% owned and where we have the ability to influence the operating or financial decisions of the affiliate, are accounted for using the equity method. In 2016, we adopted Accounting Standard Update (ASU) 2015-03, Simplifying the Presentation of Debt Issuance Costs Consolidated Balance Sheet In 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements – Going Concern
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 E&P segment recognizes revenue from the sale of crude oil, natural gas liquids, and natural gas, when title passes to the customer. Differences between E&P natural gas volumes sold and our entitlement share of natural gas production are not material. In our E&P activities, we engage 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 Our Bakken Midstream segment recognizes revenue from fee-based services including crude oil and natural gas gathering, processing of natural gas and the fractionation of natural gas liquids, terminaling and loading crude oil and natural gas liquids, transportation of crude oil by rail car and the storage and terminaling of propane when pervasive evidence of an arrangement exists, delivery has occurred or services rendered, price is fixed or determinable, and collectability is reasonably assured.
Exploration and Development Costs	HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 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 CO 2 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. 1
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization: We record 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 facilities 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: We review 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 prevailing low crude oil price environment, we tested our oil and gas properties for impairment. See Note 6, Impairment .
Impairment of Goodwill	Impairment of Goodwill: Goodwill is tested for impairment annually on October 1 st Note 6, Impairment.
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.
Income Taxes	Income Taxes: Deferred income taxes are determined using the liability method. We have net operating loss carryforwards or credit carryforwards in multiple jurisdictions and have recorded deferred tax assets for those losses and credits. Additionally, we have 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, when tested under the relevant accounting standards, 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. The accounting standards require the evaluation of all available positive and negative evidence giving weight based on the evidence’s relative objectivity. In evaluating potential sources of positive evidence, we consider the reversal of taxable temporary differences, taxable income in carryback and carryforward periods, the availability of tax planning strategies, the existence of appreciated assets, estimates of future taxable income, and other factors. In evaluating potential sources of negative evidence, we consider a cumulative loss in recent years, any history of operating losses or tax credit carryforwards expiring unused, losses expected in early future years, unsettled circumstances that, if unfavorably resolved, would adversely affect future operations and profit levels on a continuing basis in future years, and carryback or carryforward periods that are so brief that it would limit realization of tax benefits if a significant deductible temporary difference is expected to reverse in a single year. We assign cumulative historical losses significant weight in the evaluation of realizability relative to more subjective evidence such as forecasts of future income. In addition, we recognize 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. We do not provide for deferred U.S. income taxes for that portion of undistributed earnings of foreign subsidiaries that are indefinitely reinvested in foreign operations. We classify interest and penalties associated with uncertain tax positions as income tax expense.
Asset Retirement Obligations	Asset Retirement Obligations: We have material legal obligations to remove and dismantle long ‑lived assets and to restore land or the seabed at certain exploration and production locations. We initially recognize a liability for the fair value of legally required asset retirement obligations in the period in which the retirement obligations are incurred, and capitalize the associated asset retirement costs as part of the carrying amount of the long‑lived assets. In subsequent periods, the liability is accreted, and the asset is depreciated over the useful life of the related asset. Fair value is determined by applying a credit adjusted risk-free rate to the undiscounted expected future abandonment expenditures, which represent Level 3 inputs in the fair value hierarchy defined under Fair Value Measurements below.
Retirement Plans	Retirement Plans: We recognize 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. We recognize the net changes in the funded status of these plans in the year in which such changes occur. 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 or the remaining average expected life if a plan’s participants are predominantly inactive.
Derivatives	Derivatives: We utilize derivative instruments for financial risk management activities. In these activities, we may use futures, forwards, options and swaps, individually or in combination, to mitigate our exposure to fluctuations in prices of crude oil and natural gas, as well as changes in interest and foreign currency exchange rates. All derivative instruments are recorded at fair value in our Consolidated Balance Sheet
Fair Value Measurements	Fair Value Measurements: We use various valuation approaches in determining fair value for financial instruments, including the market and income approaches. Our fair value measurements also include non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and our credit is considered for accrued liabilities. We also record 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. We determine 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), including discounted cash flows and other unobservable data. 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. 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. Netting of Financial Instruments: We generally enter 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 our intent and practice is to offset amounts in the case of such a termination, our policy is to record the fair value of derivative assets and liabilities on a net basis. In the normal course of business, we rely 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 us, “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. We are 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.
Share-based Compensation	Share-based Compensation: We account for share-based compensation under the fair value method of accounting. 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. We estimate 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 remeasuring 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: We accrue and expense 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 2016, our reserve for estimated remediation liabilities was approximately $80 million. 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 May 2014, the Financial Accounting Standards Board (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 us beginning in the first quarter of 2018, with early adoption permitted from the first quarter of 2017. We have developed a project plan for the implementation of ASC 606 in the first quarter of 2018, and conducted an evaluation of a sample of revenue contracts with customers against the requirements of the standard. Further analysis is planned in 2017 to complete the implementation plan. Based on our assessment to date, we have not identified any changes to the timing of revenue recognition based on the requirements of ASC 606 that would have a material impact on our consolidated financial statements. We plan to adopt ASC 606 using the modified retrospective method that requires application of the new standard prospectively from the date of adoption with a cumulative effect adjustment recorded to retained earnings as of January 1, 2018. In February 2016, the FASB issued ASU 2016-02, Leases In March 2016, the FASB issued Accounting Standards Update (ASU) 2016-09, Improvements to Employee Share-Based Payment Accounting. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses In October 2016, the FASB issued ASU 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory In January 2017, the FASB issued ASU 2017-01, Business Combinations – Clarifying the Definition of a Business In January 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2016
Inventory Disclosure [Abstract]
Inventories	Inventories at December 31 were as follows: 2016 2015 (In millions) Crude oil and natural gas liquids $ 77 $ 144 Materials and supplies 246 255 Total Inventories $ 323 $ 399

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
Property Plant And Equipment [Abstract]
Components of Property, Plant and Equipment	Property, plant and equipment at December 31 were as follows: 2016 2015 (In millions) Exploration and Production Unproved properties $ 710 $ 958 Proved properties 4,258 4,202 Wells, equipment and related facilities 38,821 38,738 43,789 43,898 Bakken Midstream 3,018 2,757 Corporate and Other 100 171 Total — at cost 46,907 46,826 Less: Reserves for depreciation, depletion, amortization and lease impairment 23,312 20,474 Property, Plant and Equipment — Net $ 23,595 $ 26,352
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: 2016 2015 2014 (In millions) Balance at January 1 $ 1,415 $ 1,416 $ 2,045 Additions to capitalized exploratory well costs pending the determination of proved reserves 79 424 292 Reclassifications to wells, facilities and equipment based on the determination of proved reserves — (72 ) (629 ) Capitalized exploratory well costs charged to expense (897 ) (356 ) (235 ) Dispositions and other — 3 (57 ) Balance at December 31 $ 597 $ 1,415 $ 1,416 Number of Wells at December 31 17 35 37
Exploratory Drilling Costs Capitalized in Excess of One Year After Completion of Drilling	Exploratory well costs capitalized for greater than one year following completion of drilling were $511 million at December 31, 2016, separated by year of completion as follows (in millions): 2015 $ 238 2014 80 2013 48 2012 145 $ 511

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2016
Goodwill And Intangible Assets Disclosure [Abstract]
Changes in Carrying Amount of Goodwill	The changes in the carrying amount of goodwill were as follows: Exploration and Production Bakken Midstream Total (In millions) Balance at January 1, 2015 $ 1,858 $ — $ 1,858 Reclassification (375 ) 375 — Impairment (1,483 ) — (1,483 ) Balance at December 31, 2015 — 375 375 Reclassification — — — Impairment — — — Balance at December 31, 2016 $ — $ 375 $ 375

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Discontinued Operations And Disposal Groups [Abstract]
Summary of Sales and Other Operating Revenues and Income (Loss) from Discontinued Operations	Sales and other operating revenues and income from discontinued operations were as follows: 2016 2015 2014 (In millions) Sales and other operating revenues $ — $ 14 $ 9,576 Income (Loss) from Discontinued Operations Before Income Taxes $ — $ (74 ) $ 1,071 Current tax provision (benefit) — — — Deferred tax provision (benefit) — (26 ) 389 Provision (benefit) for income taxes — (26 ) 389 Income (loss) from Discontinued Operations, Net of Income Taxes $ — $ (48 ) $ 682 Less: Net income (loss) attributable to noncontrolling interests — — 57 Income (Loss) from Discontinued Operations Attributable to Hess Corporation $ — $ (48 ) $ 625

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Changes to Asset Retirement Obligations	The following table describes changes to our asset retirement obligations: 2016 2015 (In millions) Balance at January 1 $ 2,383 $ 2,723 Liabilities incurred 42 57 Liabilities settled or disposed of (196 ) (360 ) Accretion expense 117 126 Revisions of estimated liabilities (230 ) 92 Foreign currency translation 12 (255 ) Balance at December 31 2,128 2,383 Less: Current Obligations 216 225 Long-term Obligations at end of period $ 1,912 $ 2,158

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Components of Debt	Long‑term debt at December 31 consisted of the following: 2016 2015 (In millions) Debt Excluding Bakken Midstream: Fixed-rate public notes: 1.3% due 2017 $ — $ 299 8.1% due 2019 349 996 3.5% due 2024 297 296 4.3% due 2027 989 — 7.9% due 2029 499 693 7.3% due 2031 679 744 7.1% due 2033 596 595 6.0% due 2040 740 739 5.6% due 2041 1,232 1,231 5.8% due 2047 493 — Total fixed-rate public notes 5,874 5,593 Financing obligations associated with floating production system 192 264 Fair value adjustments - interest rate hedging 7 31 Total Debt Excluding Bakken Midstream $ 6,073 $ 5,888 Debt Related to Bakken Midstream Bakken Midstream - term loan A facility $ 580 $ 594 Bakken Midstream - revolving credit facility 153 110 Total Debt Related to Bakken Midstream $ 733 $ 704 Total Long-Term Debt: Total debt (a) (b) $ 6,806 $ 6,592 Less: Current maturities of long-term debt 112 86 Total Long-Term Debt $ 6,694 $ 6,506 (a) At December 31, 2016 the fair value of total debt amounted to $7,548 million (2015: $6,515 million ). (b) The
Outstanding Letters of Credit	Letters of credit: Outstanding letters of credit at December 31 were as follows: 2016 2015 (In millions) Committed lines (a) $ 1 $ 10 Uncommitted lines (a) 187 103 Total (b) $ 188 $ 113 (a) At December 31, 2016, committed and uncommitted lines have expiration dates through 2018. (b) At December 31, 2016, $27 million relates to contingent liabilities and $161 million relates to liabilities recorded in the Consolidated Balance Sheet (2015: $32 million and $81 million, respectively).

Share-based Compensation (Table

Share-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-based Compensation Expense	Share‑based compensation expense consisted of the following: 2016 2015 2014 (In millions) Restricted stock $ 45 $ 67 $ 62 Stock options 7 5 2 Performance share units 21 25 19 Share-based compensation expense before income taxes (a) $ 73 $ 97 $ 83 Income tax benefit on share-based compensation expense $ 28 $ 36 $ 31 (a)
Summary of Share-based Compensation Activity	Share‑based compensation activity consisted of the following: Performance Share Units Stock Options Restricted Stock Performance Share Units Weighted - Average Fair Value on Date of Grant Options Weighted - Average Exercise Price per Share Shares of Restricted Common Stock Weighted - Average Price on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2016 820 $ 89.43 6,911 $ 67.77 2,820 $ 75.32 Granted 447 50.94 824 44.60 1,661 44.69 Exercised — — (227 ) 53.43 — — Vested (193 ) 111.49 — — (833 ) 69.57 Forfeited (59 ) 65.11 (916 ) 55.00 (547 ) 66.98 Outstanding at December 31, 2016 1,015 $ 69.68 6,592 $ 67.15 3,101 $ 61.93
Weighted Average Assumptions Utilized to Estimate Fair Value of Stock Options	The following weighted average assumptions were utilized to estimate the fair value of stock options: 2016 2015 2014 Risk free interest rate 1.47 % 1.77 % 1.86 % Stock price volatility 0.326 0.312 0.363 Dividend yield 2.26 % 1.34 % 1.24 % Expected life in years 6.0 6.0 6.0 Weighted average fair value per option granted $ 11.33 $ 21.00 $ 26.46
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: 2016 2015 2014 Risk free interest rate 0.96 % 1.02 % 0.65 % Stock price volatility 0.329 0.270 0.359 Contractual term in years 3.0 3.0 3.0 Grant date price of Hess common stock $ 44.31 $ 74.49 $ 80.35

Retirement Plans (Tables)

Retirement Plans (Tables)	12 Months Ended
	Dec. 31, 2016
Compensation And Retirement Disclosure [Abstract]
Change in Benefit Obligation, Fair Value of Plan Assets, and Funded Status of Pension Plans and Postretirement Medical Plan	The following table summarizes the benefit obligations, the fair value of plan assets, and the funded status of our pension and postretirement medical plans: Funded Unfunded Postretirement Pension Plans Pension Plan Medical Plan 2016 2015 2016 2015 2016 2015 (In millions) Change In Benefit Obligation Balance at January 1 $ 2,321 $ 2,450 $ 259 $ 278 $ 98 $ 94 Service cost 44 51 16 16 4 4 Interest cost 98 93 9 9 3 3 Actuarial loss (gain) (a) 162 (156 ) (5 ) (2 ) (13 ) 5 Benefit payments (b) (132 ) (85 ) (23 ) (42 ) (8 ) (8 ) Plan curtailments (2 ) (4 ) — — — — Special termination benefits 1 1 — — — — Assumption of HOVENSA pension plan 151 — — — — — Foreign currency exchange rate changes (83 ) (29 ) — — — — Balance at December 31 2,560 2,321 256 259 84 98 Change In Fair Value of Plan Assets Balance at January 1 $ 2,206 $ 2,251 $ — $ — $ — $ — Actual return on plan assets 153 28 — — — — Employer contributions 26 44 23 42 8 8 Benefit payments (b) (132 ) (85 ) (23 ) (42 ) (8 ) (8 ) Assumption of HOVENSA pension plan 126 — — — — — Foreign currency exchange rate changes (95 ) (32 ) — — — — Balance at December 31 2,284 2,206 — — — — Funded Status (Plan assets greater (less) than benefit obligations) at December 31 $ (276 ) $ (115 ) $ (256 ) $ (259 ) $ (84 ) $ (98 ) Unrecognized Net Actuarial (Gains) Losses $ 895 $ 775 $ 93 $ 105 $ (13 ) $ — (a) The change in discount rate in 2016 resulted in total actuarial losses of approximately $175 million. (b) Benefit payments include lump-sum settlement payments of $65 million in 2016 (2015: $41 million).
Pension Plans and Postretirement Medical Plan 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 2016 2015 2016 2015 2016 2015 (In millions) Pension asset / (accrued benefit liability) $ (276 ) $ (115 ) $ (256 ) $ (259 ) $ (84 ) $ (98 ) Accumulated other comprehensive loss, pre-tax (a) 895 775 93 105 (13 ) — (a) The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $660 million at December 31, 2016 (2015: $563 million deficit).
Components of Net Periodic Benefit Cost for Funded and Unfunded Pension Plans and Postretirement Medical Plan	The net periodic benefit cost for funded and unfunded pension plans, and the postretirement medical plan, is as follows: Pension Plans Postretirement Medical Plan 2016 2015 2014 2016 2015 2014 (In millions) Service cost $ 60 $ 67 $ 57 $ 4 $ 4 $ 4 Interest cost 107 102 100 3 3 3 Expected return on plan assets (166 ) (168 ) (161 ) — — — Amortization of unrecognized net actuarial losses 60 75 32 — — — Settlement loss — 17 24 — — — Special termination benefit recognized 1 1 1 — — — Net Periodic Benefit Cost $ 62 $ 94 $ 53 $ 7 $ 7 $ 7
Actuarial Assumptions Used For Pension Plans & Postretirement Medical Plan	The weighted average actuarial assumptions used for funded and unfunded pension plans were as follows: 2016 2015 2014 Weighted Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.7 % 4.1 % 3.8 % Rate of compensation increase 4.6 % 4.5 % 5.0 % Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31 Discount rate 4.1 % 3.8 % 4.6 % Expected return on plan assets 7.4 % 7.5 % 7.5 % Rate of compensation increase 4.5 % 5.0 % 4.4 % The actuarial assumptions used for postretirement medical plan, as follows: 2016 2015 2014 Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.5 % 3.5 % 3.1 % Initial health care trend rate 7.7 % 6.7 % 6.8 % Ultimate trend rate 4.5 % 4.5 % 4.5 % Year in which ultimate trend rate is reached 2038 2038 2029
Fair Value of Financial Assets of Funded Pension Plans	The following tables provide the fair value of the financial assets of the funded pension plans as of December 31, 2016 and 2015 in accordance with the fair value measurement hierarchy described in Note 1, Nature of Operations, Basis of Presentation and Summary of Accounting Policies Level 1 Level 2 Level 3 Total (In millions) December 31, 2016 Cash and Short-Term Investment Funds $ 9 $ 79 $ — $ 88 Equities: U.S. equities (domestic) 550 — — 550 International equities (non-U.S.) 160 275 — 435 Global equities (domestic and non-U.S.) 2 197 — 199 Fixed Income: Treasury and government issued (a) — 202 — 202 Government related (b) — 38 — 38 Mortgage-backed securities (c) — 164 2 166 Corporate 1 186 — 187 Other: Hedge funds — — 209 209 Private equity funds — — 126 126 Real estate funds 10 — 52 62 Diversified commodities funds — 22 — 22 $ 732 $ 1,163 $ 389 $ 2,284 December 31, 2015 Cash and Short-Term Investment Funds $ — $ 34 $ — $ 34 Equities: U.S. equities (domestic) 556 — — 556 International equities (non-U.S.) 159 266 — 425 Global equities (domestic and non-U.S.) 2 217 — 219 Fixed Income: Treasury and government issued (a) — 213 — 213 Government related (b) — 6 1 7 Mortgage-backed securities (c) — 174 2 176 Corporate — 157 — 157 Other: Hedge funds — — 216 216 Private equity funds — — 122 122 Real estate funds 12 — 52 64 Diversified commodities funds — 17 — 17 $ 729 $ 1,084 $ 393 $ 2,206 (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.
Changes in Financial Assets that are Measured at Fair Value Based on Level 3 Inputs that are 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, 2015 $ 2 $ 302 $ 105 $ 48 $ 457 Actual return on plan assets — (5 ) 18 9 22 Purchases, sales or other settlements 1 (81 ) (1 ) (5 ) (86 ) Net transfers in (out) of Level 3 — — — — — Balance at December 31, 2015 3 216 122 52 393 Actual return on plan assets — (7 ) 5 7 5 Purchases, sales or other settlements (1 ) — (1 ) (7 ) (9 ) Net transfers in (out) of Level 3 — — — — — Balance at December 31, 2016 $ 2 $ 209 $ 126 $ 52 $ 389
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): 2017 $ 138 2018 123 2019 133 2020 135 2021 136 Years 2022 to 2026 725

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Components of Income Tax Provision (Benefit) for Continuing Operations	The provision (benefit) for income taxes from continuing operations consisted of: 2016 2015 2014 (In millions) United States Federal Current $ (27 ) $ (7 ) $ (1 ) Deferred taxes and other accruals 1,948 (995 ) 156 State 23 (61 ) 57 1,944 (1,063 ) 212 Foreign Current 36 4 453 Deferred taxes and other accruals 235 (231 ) 79 271 (227 ) 532 Total 2,215 (1,290 ) 744 Adjustment of deferred taxes for foreign income tax law changes 7 (9 ) — Total Provision (Benefit) For Income Taxes (a) $ 2,222 $ (1,299 ) $ 744 (a) Includes charges of $3,749 million in 2016 to establish valuation allowances on net deferred tax assets which is discussed further below.
Income (Loss) From Continuing Operations Before Income Taxes	Income (loss) from continuing operations before income taxes consisted of the following: 2016 2015 2014 (In millions) United States (a) $ (2,431 ) $ (2,728 ) $ 676 Foreign (1,423 ) (1,530 ) 1,760 Total Income (Loss) from Continuing Operations Before Income Taxes $ (3,854 ) $ (4,258 ) $ 2,436 (a) Includes substantially all of our interest expense, corporate expense and the results of commodity hedging activities.
Components of Deferred Tax Liabilities and Deferred Tax Assets, and Presentation in Consolidated Balance Sheet	The components of deferred tax liabilities and deferred tax assets at December 31 were as follows: 2016 2015 (In millions) Deferred Tax Liabilities Property, plant and equipment and investments $ (3,810 ) $ (3,743 ) Other (255 ) (257 ) Total Deferred Tax Liabilities (4,065 ) (4,000 ) Deferred Tax Assets Net operating loss carryforwards 5,767 3,852 Tax credit carryforwards 164 188 Property, plant and equipment and investments 834 981 Accrued compensation, deferred credits and other liabilities 526 492 Asset retirement obligations 1,077 1,220 Other 62 165 Total Deferred Tax Assets 8,430 6,898 Valuation allowances (5,450 ) (1,579 ) Total deferred tax assets, net of valuation allowances 2,980 5,319 Net Deferred Tax Assets (Liabilities) $ (1,085 ) $ 1,319 In the Consolidated Balance Sheet 2016 2015 (In millions) Deferred income taxes (long-term asset) $ 59 $ 2,653 Deferred income taxes (long-term liability) (1,144 ) (1,334 ) Net Deferred Tax Assets (Liabilities) $ (1,085 ) $ 1,319
Effective Income Tax Rate Reconciliation for Continuing Operations	The difference between our effective income tax rate from continuing operations and the U.S. statutory rate is reconciled below: 2016 2015 2014 U.S. statutory rate 35.0 % 35.0 % 35.0 % Effect of foreign operations (a) 4.6 5.9 0.7 State income taxes, net of Federal income tax 1.9 0.9 1.5 Change in enacted tax laws (0.2 ) 0.2 — Gains on asset sales, net — (0.2 ) (8.3 ) Impairment (2.1 ) (12.2 ) — Valuation allowance against previously benefitted deferred tax assets (97.3 ) (3.1 ) 0.6 Benefit of legal entity restructuring — 3.5 — Other 0.4 0.5 1.0 Total (57.7 ) % 30.5 % 30.5 % (a) The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the mix of income among high and low tax rate jurisdictions.
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: 2016 2015 (In millions) Balance at January 1 $ 604 $ 603 Additions based on tax positions taken in the current year 19 19 Additions based on tax positions of prior years 113 29 Reductions based on tax positions of prior years (274) (31) Reductions due to settlements with taxing authorities (27) (12) Reductions due to lapses in statutes of limitation (11) (4) Balance at December 31 $ 424 $ 604

Outstanding and Weighted Aver43

Outstanding and Weighted Average Common Shares (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Changes in Outstanding Common Shares	The following table provides the changes in our outstanding common shares: 2016 2015 2014 (In millions) Balance at January 1 286.0 285.8 325.3 Shares issued 28.8 — — Activity related to restricted stock awards, net 1.1 0.8 0.6 Stock options exercised 0.2 0.2 3.3 PSU vested 0.4 0.6 — Shares repurchased (a) — (1.4 ) (43.4 ) Balance at December 31 316.5 286.0 285.8 (a) See Note 18, Share Repurchase Plan.
Net Income (Loss) and Computation of Basic and Diluted Earnings Per Share	The following table presents the calculation of basic and diluted earnings per share: 2016 2015 2014 (In millions, except per share amounts) Net Income (Loss) Attributable to Hess Corporation Common Stockholders: Income (loss) from continuing operations, net of income taxes $ (6,076 ) $ (2,959 ) $ 1,692 Less: Net income (loss) attributable to noncontrolling interests 56 49 — Net income (loss) from continuing operations attributable to Hess Corporation (6,132 ) (3,008 ) 1,692 Less: Preferred stock dividends 41 — — Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders (6,173 ) (3,008 ) 1,692 Income (loss) from discontinued operations, net of income taxes — (48 ) 682 Less: Net income (loss) attributable to noncontrolling interests — — 57 Net income (loss) from discontinued operations attributable to Hess Corporation — (48 ) 625 Net income (loss) attributable to Hess Corporation Common Stockholders $ (6,173 ) $ (3,056 ) $ 2,317 Weighted Average Number of Common Shares Outstanding: Basic 309.9 283.6 303.7 Effect of dilutive securities Restricted common stock — — 1.5 Stock options — — 1.8 Performance share units — — 0.7 Mandatory Convertible Preferred stock — — — Diluted 309.9 283.6 307.7 Net Income (Loss) Attributable to Hess Corporation per Common Share: Basic: Continuing operations $ (19.92 ) $ (10.61 ) $ 5.57 Discontinued operations — (0.17 ) 2.06 Net income (loss) per common share $ (19.92 ) $ (10.78 ) $ 7.63 Diluted: Continuing operations $ (19.92 ) $ (10.61 ) $ 5.50 Discontinued operations — (0.17 ) 2.03 Net income (loss) per common share $ (19.92 ) $ (10.78 ) $ 7.53
Summary of Antidilutive Shares Excluded from Computation of Diluted Shares	The following table summarizes the number of antidilutive shares excluded from the computation of diluted shares: 2016 2015 2014 (In millions) Restricted common stock 3.3 2.9 — Stock options 6.9 6.9 1.4 Performance share units 0.9 1.0 — Common shares from conversion of preferred stock 11.2 — —

Share Repurchase Plan (Tables)

Share Repurchase Plan (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Schedule of Share Repurchases Under Share Repurchase Plan	Repurchases under this program to date have been as follows: 2016 2015 2014 To Date (In millions) Total cost of shares repurchased $ — $ 91 $ 3,722 $ 5,351 Total number of shares repurchased — 1.45 43.35 64.11

Supplementary Cash Flow Infor45

Supplementary Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Supplementary Cash Flow Information for Statement of Consolidated Cash Flows	The following information supplements the Statement of Consolidated Cash Flows 2016 2015 2014 (In millions) Cash Flows From Operating Activities Interest paid $ (338 ) $ (331 ) $ (326 ) Net income taxes (paid) refunded 132 (140 ) (455 ) Cash Flows From Investing Activities Capital expenditures incurred - E&P (1,645 ) (3,753 ) (4,920 ) Increase (decrease) in related liabilities (334 ) (203 ) 53 Additions to property, plant and equipment - E&P (1,979 ) (3,956 ) (4,867 ) Capital expenditures incurred - Bakken Midstream (276 ) (296 ) (301 ) Increase (decrease) in related liabilities 4 (69 ) (46 ) Additions to property, plant and equipment - Bakken Midstream (272 ) (365 ) (347 ) Cash Flows From Financing Activities Contribution from formation of Bakken Midstream joint venture — 2,628 — Distributions to partner in Bakken Midstream joint venture (23 ) (332 ) — Noncontrolling interests, net related to Continuing operations (23 ) 2,296 — Significant Non-Cash Transactions Increase in debt due to construction of a floating production system - Tubular Bells Field $ — $ — $ 68

Leased Assets (Tables)

Leased Assets (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Future Minimum Rental Payments	At December 31, 2016, 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): 2017 $ 376 2018 375 2019 351 2020 124 2021 67 Remaining years 338 Total Minimum Lease Payments 1,631 Less: Income from subleases 78 Net Minimum Lease Payments $ 1,553
Rental Expense	Rental expense was as follows: 2016 2015 2014 (In millions) Total rental expense $ 106 $ 167 $ 248 Less: Income from subleases 5 10 17 Net Rental Expense $ 101 $ 157 $ 231

Guarantees, Contingencies and47

Guarantees, Contingencies and Commitments (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Schedule of Unconditional Purchase Obligations and Commitments	The following table shows aggregate information for certain unconditional purchase obligations and commitments at December 31, 2016 which are not included elsewhere within these Consolidated Financial Statements Payments Due by Period 2018 and 2020 and Total 2017 2019 2021 Thereafter (In millions) Capital expenditures $ 708 $ 632 $ 76 $ — $ — Operating expenses 497 393 76 18 10 Transportation and related contracts 1,560 182 457 433 488

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Financial Data by Operating Segment	The following table presents operating segment financial data for continuing operations (in millions): 2016 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 4,762 $ — $ — $ — $ 4,762 Intersegment Revenues — 510 — (510 ) — Operating Revenues $ 4,762 $ 510 $ — $ (510 ) $ 4,762 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ (4,963 ) $ 41 $ (1,210 ) $ — $ (6,132 ) Interest Expense — 19 319 — 338 Depreciation, Depletion and Amortization 3,132 102 10 — 3,244 Impairment — 67 — — 67 Provision (Benefit) for Income Taxes 1,588 25 609 — 2,222 Investment in Affiliates 146 — — — 146 Identifiable Assets 23,102 2,919 2,600 — 28,621 Capital Expenditures 1,645 276 — — 1,921 2015 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 6,636 $ — $ — $ — $ 6,636 Intersegment Revenues — 564 — (564 ) — Operating Revenues $ 6,636 $ 564 $ — $ (564 ) $ 6,636 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ (2,717 ) $ 86 $ (377 ) $ — $ (3,008 ) Interest Expense — 10 331 — 341 Depreciation, Depletion and Amortization 3,852 88 15 — 3,955 Impairment 1,616 — — — 1,616 Provision (Benefit) for Income Taxes (1,111 ) 52 (240 ) — (1,299 ) Investment in Affiliates 154 — — — 154 Identifiable Assets 28,863 2,754 2,540 — 34,157 Capital Expenditures 3,753 296 — — 4,049 2014 Exploration and Production Bakken Midstream Corporate, Interest and Other Eliminations Total Operating Revenues - Third parties $ 10,737 $ — $ — $ — $ 10,737 Intersegment Revenues — 319 — (319 ) — Operating Revenues $ 10,737 $ 319 $ — $ (319 ) $ 10,737 Net Income (Loss) from Continuing Operations Attributable to Hess Corporation $ 2,086 $ 10 $ (404 ) $ — $ 1,692 Interest Expense — 2 321 — 323 Depreciation, Depletion and Amortization 3,140 70 14 — 3,224 Provision (Benefit) for Income Taxes 989 7 (252 ) — 744 Capital Expenditures 4,920 301 53 — 5,274
Financial Information by Major Geographic Area	The following table presents financial information by major geographic area: United States Europe Africa Asia and Other Countries Corporate, Interest and other Total (In millions) 2016 Operating revenues $ 3,085 $ 610 $ 601 $ 466 $ — $ 4,762 Net income (loss) from continuing operations attributable to Hess Corporation (2,353 ) (439 ) (355 ) (1,775 ) (1,210 ) (6,132 ) Depreciation, depletion and amortization 2,133 502 375 224 10 3,244 Impairment 67 — — — — 67 Provision (benefit) for income taxes 411 243 244 715 609 2,222 Identifiable assets 16,096 5,180 1,507 3,238 2,600 28,621 Property, plant and equipment (net) (a) 14,596 4, 907 1,266 2,779 47 23,595 Capital expenditures 1,400 59 10 452 — 1,921 2015 Operating revenues $ 4,150 $ 870 $ 945 $ 671 $ — $ 6,636 Net income (loss) from continuing operations attributable to Hess Corporation (1,834 ) (408 ) (274 ) (115 ) (377 ) (3,008 ) Depreciation, depletion and amortization 2,449 635 539 317 15 3,955 Impairment 986 279 100 251 — 1,616 Provision (benefit) for income taxes (522 ) (84 ) (48 ) (405 ) (240 ) (1,299 ) Identifiable assets 18,365 6,207 2,178 4,867 2,540 34,157 Property, plant and equipment (net) (a) 15,729 5,300 1,682 3,520 121 26,352 Capital expenditures 2,727 297 160 865 — 4,049 2014 Operating revenues $ 6,270 $ 1,557 $ 2,002 $ 908 $ — $ 10,737 Net income (loss) from continuing operations attributable to Hess Corporation 654 226 545 671 (404 ) 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 Capital expenditures 3,467 524 399 831 53 5,274 (a) Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	The following table presents our related party transactions: 2016 2015 2014 (In millions) Sales: WilcoHess (a) $ — $ — $ 211 HOVENSA — — 31 (a) We acquired our partners’ 56% interest in WilcoHess in January 2014 for approximately $290 million. See Note 9, Discontinued Operations.

Financial Risk Management Act50

Financial Risk Management Activities (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Gross Notional Amounts of Financial Risk Management Derivative Contracts Outstanding	The gross notional amounts of financial risk management derivative contracts outstanding at December 31, were as follows: 2016 2015 (In millions of USD) Foreign exchange $ 785 $ 967 Interest rate swaps 350 1,300
Gross and Net Fair Values of Financial Risk Management Derivative Instruments	The table below reflects the gross and net fair values of the risk management derivative instruments, all of which are based on Level 2 inputs: Accounts Receivable Accounts Payable (In millions) December 31, 2016 Derivative Contracts Designated as Hedging Instruments Interest rate $ — $ — Total derivative contracts designated as hedging instruments — — Derivative Contracts Not Designated as Hedging Instruments Foreign exchange 9 (1 ) Total derivative contracts not designated as hedging instruments 9 (1 ) Gross fair value of derivative contracts 9 (1 ) Master netting arrangements (1 ) 1 Net Fair Value of Derivative Contracts $ 8 $ — December 31, 2015 Derivative Contracts Designated as Hedging Instruments Interest rate $ 3 $ — Total derivative contracts designated as hedging instruments 3 — Derivative Contracts Not Designated as Hedging Instruments Foreign exchange 19 (3 ) Total derivative contracts not designated as hedging instruments 19 (3 ) Gross fair value of derivative contracts 22 (3 ) Master netting arrangements (3 ) 3 Net Fair Value of Derivative Contracts $ 19 $ —

Nature of Operations, Basis o51

Nature of Operations, Basis of Presentation and Summary of Accounting Policies - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Variable interest in Hess Infrastructure Partners LP (HIP)	50.00%
Amount recast to reduce Other assets and Long-term debt as a result of adopting ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs		$ 38
Reserve for estimated remediation liabilities	$ 80

Common and Preferred Stock Is52

Common and Preferred Stock Issuance - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 29, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Class Of Stock [Line Items]
Shares of stock issued		28,750,000	0	0
Cumulative mandatory convertible series		8.00%
Preferred stock, par value		$ 1
Preferred stock, liquidation preference per share		$ 1,000
Net proceeds from issuance of common stock and Mandatory convertible preferred stock, after deducting underwriting discounts, commissions, and offering expenses	$ 1,600,000,000
Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Shares of stock issued	575,000
Cumulative mandatory convertible series	8.00%
Preferred stock, par value	$ 1
Preferred stock, liquidation preference per share	$ 1,000
Series A Mandatory Convertible Preferred Stock | Final Average Price, $45.83 or less
Class Of Stock [Line Items]
Value of capped call transaction	$ 0
Series A Mandatory Convertible Preferred Stock | Final Average Price, $53.625 or higher
Class Of Stock [Line Items]
Value of capped call transaction	$ 98,000,000
Series A Mandatory Convertible Preferred Stock | Final Average Price between $45.83 and $53.625
Class Of Stock [Line Items]
Number of shares multiplied by difference between the final average price	12,550,000
Series A Mandatory Convertible Preferred Stock | Minimum
Class Of Stock [Line Items]
Number of shares issued for each share of convertible preferred stock that is converted	21.822
Series A Mandatory Convertible Preferred Stock | Maximum
Class Of Stock [Line Items]
Number of shares issued for each share of convertible preferred stock that is converted	25.642
Common Stock
Class Of Stock [Line Items]
Shares of stock issued	28,750,000
Capital in Excess of Par | Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Premium paid for capped call transaction	$ 37,000,000

Inventories - Inventories (Deta

Inventories - Inventories (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 77	$ 144
Materials and supplies	246	255
Total Inventories	$ 323	$ 399

Property, Plant and Equipment -

Property, Plant and Equipment - Components of Property, Plant and Equipment (Detail) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Total — at cost		$ 46,907	$ 46,826
Less: Reserves for depreciation, depletion, amortization and lease impairment		23,312	20,474
Property, Plant and Equipment — Net	[1]	23,595	26,352
Exploration and Production
Property Plant And Equipment [Line Items]
Unproved properties		710	958
Proved properties		4,258	4,202
Wells, equipment and related facilities		38,821	38,738
Total — at cost		43,789	43,898
Bakken Midstream
Property Plant And Equipment [Line Items]
Total — at cost		3,018	2,757
Corporate and Other
Property Plant And Equipment [Line Items]
Total — at cost		$ 100	$ 171
[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Property, Plant and Equipment55

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)Well	Dec. 31, 2015USD ($)Well	Dec. 31, 2014USD ($)Well
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 1,415	$ 1,416	$ 2,045
Additions to capitalized exploratory well costs pending the determination of proved reserves	79	424	292
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	0	(72)	(629)
Capitalized exploratory well costs charged to expense	(897)	(356)	(235)
Dispositions and other	0	3	(57)
Ending balance	$ 597	$ 1,415	$ 1,416
Number of Wells at December 31 | Well	17	35	37

Property, Plant and Equipment56

Property, Plant and Equipment - Capitalized Exploratory Well Costs - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)km²Well	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Capitalized Exploratory Well Costs [Line Items]
Expenses on capitalized exploratory well costs associated with project	$ 597	$ 1,415	$ 1,416	$ 2,045
Exploratory dry hole costs which were incurred and subsequently expensed	167	$ 54	$ 66
Capitalized exploratory well costs that have been capitalized for period greater than one year	511
Non-operated Sicily Project And Melmar Project, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Expenses on capitalized exploratory well costs associated with project	$ 830
Deepwater Tano/Cape Three Points License, Offshore Ghana
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	55.00%
Percentage of ownership interest on license	50.00%
This number of approved appraisal wells is completed | Well	3
Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	20.00%
Participating interest rate on exploration well	30.00%
Area of exploratory well completed | km²	17,000
Northern Portion of Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	20.00%
Participating interest rate on exploration well	28.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	5.00%

Property, Plant and Equipment57

Property, Plant and Equipment - Exploratory Drilling Costs Capitalized (Detail) $ in Millions	Dec. 31, 2016USD ($)
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	$ 511
Year 2,015
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	238
Year 2,014
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	80
Year 2,013
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	48
Year 2,012
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	$ 145

Goodwill - Changes in Carrying

Goodwill - Changes in Carrying Amount of Goodwill (Detail) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Line Items]
Balance at January 1	$ 1,858	$ 375	$ 1,858
Reclassification		0	0
Impairment		0	(1,483)
Balance at December 31		375	375
Exploration and Production
Goodwill [Line Items]
Balance at January 1	1,858	0	1,858
Reclassification		0	(375)
Impairment		0	(1,483)
Balance at December 31		0	0
Bakken Midstream
Goodwill [Line Items]
Balance at January 1	0	375	0
Reclassification	$ 375	0	375
Impairment		0	0
Balance at December 31		$ 375	$ 375

Goodwill - Additional Informati

Goodwill - Additional Information (Detail) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)Segment	Jun. 30, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Goodwill [Line Items]
Number of reporting units in Exploration and Production segment | Segment	2
Goodwill			$ 375	$ 375	$ 1,858
Reclassification			0	0
Offshore Reporting Unit of Exploration and Production Segment
Goodwill [Line Items]
Goodwill	$ 1,098	$ 1,098
Onshore Reporting Unit of Exploration and Production Segment
Goodwill [Line Items]
Goodwill	$ 760	760
Bakken Midstream
Goodwill [Line Items]
Goodwill			375	375	$ 0
Reclassification		$ 375	$ 0	$ 375

Impairment - Additional Informa

Impairment - Additional Information (Detail) - USD ($)	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impairments [Line Items]
Impairment charge, pre-tax		$ 67,000,000	$ 1,616,000,000	$ 0
Impairment charge, after-tax and noncontrolling interest		21,000,000
Goodwill impairment charge, pre-tax		$ 0	1,483,000,000
Goodwill impairment charge, after-tax			1,483,000,000
Legacy conventional North Dakota Assets
Impairments [Line Items]
Impairment charge, pre-tax			133,000,000
Impairment charge, after-tax			83,000,000
Onshore Reporting Unit - Post Segment Change
Impairments [Line Items]
Goodwill impairment charge, pre-tax			385,000,000
Offshore Reporting Unit - Post Segment Change
Impairments [Line Items]
Goodwill impairment charge, pre-tax			1,098,000,000
Bakken Midstream
Impairments [Line Items]
Goodwill impairment charge, pre-tax			$ 0
Offshore and Onshore Reporting Units - Pre-segment Change
Impairments [Line Items]
Goodwill impairment charge, pre-tax	$ 0

Bakken Midstream Joint Venture

Bakken Midstream Joint Venture - Additional Information (Detail) - USD ($) $ in Millions		Jul. 02, 2015	Jul. 01, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2013
Bakken Midstream Joint Venture [Line Items]
Percentage interest sold of Hess Infrastructure Partners			50.00%
Proceeds from sale of interest in Hess Infrastructure Partners			$ 2,628	$ 0	$ 2,628	$ 0
Term of tariff agreements between Hess Corporation and the Bakken Midstream							10 years
Additional renewal period of tariff agreements by Bakken Midstream							10 years
Hess Corporation's ownership percentage in Bakken Midstream				50.00%
After tax gain from sale of equity interest					2,061
Noncontrolling interest, ownership percentage				50.00%			50.00%
Cash and cash equivalents				$ 2,732	2,716	$ 2,444	$ 2,732	$ 1,814
Property, plant and equipment, net	[1]			23,595	26,352		23,595
Bakken Midstream
Bakken Midstream Joint Venture [Line Items]
Term Loan A facility - Face amount			$ 600	$ 600	$ 600		600
Term Loan A facility - Term		5 years	5 years	5 years	5 years
HIP
Bakken Midstream Joint Venture [Line Items]
Cash and cash equivalents				$ 2	$ 3		2
Property, plant and equipment, net				$ 2,528	2,358		$ 2,528
Bakken Midstream liabilities non-recourse to Hess Corporation				liabilities totaling $841 million (2015: $831 million)
Capital in Excess of Par
Bakken Midstream Joint Venture [Line Items]
After tax gain from sale of equity interest					763
Noncontrolling Interests
Bakken Midstream Joint Venture [Line Items]
After tax gain from sale of equity interest					$ 1,298
[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Dispositions - Additional Infor

Dispositions - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)a	Dec. 31, 2014USD ($)a
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales	$ 140,000,000	$ 50,000,000	$ 2,978,000,000
Gains (loss) on asset sales, net	23,000,000	51,000,000	823,000,000
Gain (loss) on asset sale, after-tax			0
Interests in Pangkah Asset, Offshore Indonesia
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			650,000,000
Gains (loss) on asset sales, net			31,000,000
Gain (loss) on asset sale, after-tax			(10,000,000)
Interests in Thailand
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			805,000,000
Gains (loss) on asset sales, net			706,000,000
Gain (loss) on asset sale, after-tax			706,000,000
Joint Venture Interest in an Electric Generating Facility in Newark, New Jersey
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			320,000,000
Gains (loss) on asset sales, net			13,000,000
Gain (loss) on asset sale, after-tax			8,000,000
Joint Venture Interest in Bayonne Energy Center
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			79,000,000
Interest in an Exploration Asset in United Kingdom North Sea
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			53,000,000
Gains (loss) on asset sales, net			33,000,000
Gain (loss) on asset sale, after-tax			33,000,000
Interest in Algeria
Disposition Of Businesses [Line Items]
Gains (loss) on asset sales, net		(21,000,000)
Gain (loss) on asset sale, after-tax		(21,000,000)
Miscellaneous Non-core Assets
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales	100,000,000
Gains (loss) on asset sales, net	23,000,000
Gain (loss) on asset sale, after-tax	$ 14,000,000
Net Acres in Utica Dry Gas Area of Utica Shale
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales			1,075,000,000
Gains (loss) on asset sales, net		49,000,000	62,000,000
Gain (loss) on asset sale, after-tax		$ 31,000,000	$ 35,000,000
Net acres of Utica dry gas acreage sold | a		13,000	77,000
Sales price of Utica dry gas acreage sold		$ 120,000,000
Joint Venture Interest in Bayonne Energy Center
Disposition Of Businesses [Line Items]
Cash proceeds from asset sales		20,000,000
Gains (loss) on asset sales, net		20,000,000
Gain (loss) on asset sale, after-tax		$ 13,000,000

Discontinued Operations - Summa

Discontinued Operations - Summary of Sales and Other Operating Revenues and Income (Loss) from Discontinued Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Discontinued Operations And Disposal Groups [Abstract]
Sales and other operating revenues	$ 0	$ 14	$ 9,576
Income (Loss) from Discontinued Operations Before Income Taxes	0	(74)	1,071
Current tax provision (benefit)	0	0	0
Deferred tax provision (benefit)	0	(26)	389
Provision (benefit) for income taxes	0	(26)	389
Income (loss) from Discontinued Operations, Net of Income Taxes	0	(48)	682
Less: Net income (loss) attributable to noncontrolling interests	0	0	57
Income (Loss) from Discontinued Operations Attributable to Hess Corporation	$ 0	$ (48)	$ 625

Discontinued Operations - Addit

Discontinued Operations - Additional Information (Detail) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2014USD ($)	Dec. 31, 2014USD ($)Lease
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Percentage of interest in WilcoHess acquired for preparation of its subsequent sale with retail business	56.00%	56.00%
Cost of acquiring additional ownership interest in WilcoHess	$ 290
Retail Business
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Cash proceeds from sale of business		$ 2,800
Gain (loss) from sale of business, pre-tax		954
Gain (loss) from sale of business, after-tax		602
Goodwill associated with divested business		115
Gain (loss) related to liquidation of LIFO inventory associated with divested business, pre-tax		275
Gain (loss) related to liquidation of LIFO inventory associated with divested business, after-tax		171
Charges for impairments, environmental matters, severance and exit costs associated with divested business, pre-tax		308
Charges for impairments, environmental matters, severance and exit costs associated with divested business, after-tax		202
Charges related to termination of lease contracts and purchase of retail gasoline stations, pre-tax		115
Charges related to termination of lease contracts and purchase of retail gasoline stations, after-tax		$ 72
Number of retail gasoline stations purchased in preparation for subsequent sale of retail business | Lease		180
Original ownership interest held in WilcoHess		44.00%
Cost of acquiring additional ownership interest in WilcoHess		$ 290
Gain (loss) from remeasurement of carrying value of original equity interest of WilcoHess to fair value, pre-tax		39
Gain (loss) from remeasurement of carrying value of original equity interest of WilcoHess to fair value, after-tax		24
Goodwill acquired during period		$ 115

HOVENSA LLC - Additional Inform

HOVENSA LLC - Additional Information (Detail) - HOVENSA - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2016
Bankruptcy Proceedings And Liquidation Plan [Line Items]
Interest in joint venture	50.00%	50.00%
Debtor-in-possession, credit facility	$ 40
Estimated net difference between pension plan obligation and fair value of plan assets	$ 30

Asset Retirement Obligations -

Asset Retirement Obligations - Changes to Asset Retirement Obligations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 2,383	$ 2,723
Liabilities incurred	42	57
Liabilities settled or disposed of	(196)	(360)
Accretion expense	117	126
Revisions of estimated liabilities	(230)	92
Foreign currency translation	12	(255)
Asset retirement obligations at end of period	2,128	2,383
Less: Current Obligations	216	225
Long-term Obligations at end of period	$ 1,912	$ 2,158

Asset Retirement Obligations 67

Asset Retirement Obligations - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation [Line Items]
Fair value of sinking fund deposits legally restricted for purposes of settling asset retirement obligations	$ 102	$ 79
Drilling License | South Arne Field, offshore Denmark
Asset Retirement Obligation [Line Items]
License agreement extension period	20 years
License agreement expiration year	2,047

Debt - Components of Debt (Deta

Debt - Components of Debt (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Total debt	$ 6,806	$ 6,592
Less: Current maturities of long-term debt	112	86
Total long-term debt	6,694	6,506
Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	5,874	5,593
Financing obligations associated with floating production system	192	264
Fair value adjustments - interest rate hedging	7	31
Total debt	6,073	5,888
Bakken Midstream
Debt Instrument [Line Items]
Total debt	733	704
Bakken Midstream - term loan A facility	580	594
Revolving credit facility - Outstanding amount	153	110
1.3% Due 2017 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	0	299
8.1% Due 2019 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	349	996
3.5% Due 2024 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	297	296
4.3% due 2027 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	989	0
7.9% Due 2029 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	499	693
7.3% Due 2031 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	679	744
7.1% Due 2033 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	596	595
6.0% Due 2040 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	740	739
5.6% Due 2041 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	1,232	1,231
5.8% due 2047 | Debt Excluding Bakken Midstream
Debt Instrument [Line Items]
Fixed-rate public notes	$ 493	$ 0

Debt - Components of Debt (Pare

Debt - Components of Debt (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2016
1.3% Due 2017
Debt Instrument [Line Items]
Coupon rate	1.30%
Maturity year	2,017
8.1% Due 2019
Debt Instrument [Line Items]
Coupon rate	8.10%
Maturity year	2,019
3.5% Due 2024
Debt Instrument [Line Items]
Coupon rate	3.50%
Maturity year	2,024
4.3% due 2027
Debt Instrument [Line Items]
Coupon rate	4.30%
Maturity year	2,027
7.9% Due 2029
Debt Instrument [Line Items]
Coupon rate	7.90%
Maturity year	2,029
7.3% Due 2031
Debt Instrument [Line Items]
Coupon rate	7.30%
Maturity year	2,031
7.1% Due 2033
Debt Instrument [Line Items]
Coupon rate	7.10%
Maturity year	2,033
6.0% Due 2040
Debt Instrument [Line Items]
Coupon rate	6.00%
Maturity year	2,040
5.6% Due 2041
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2,041
5.8% due 2047
Debt Instrument [Line Items]
Coupon rate	5.80%
Maturity year	2,047

Debt - Additional Information (

Debt - Additional Information (Detail) - USD ($)	Jul. 02, 2015	Jul. 01, 2015	Oct. 31, 2016	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Aggregate long-term debt, maturing in 2017					$ 112,000,000
Aggregate long-term debt, maturing in 2018					123,000,000
Aggregate long-term debt, maturing in 2019					448,000,000
Aggregate long-term debt, maturing in 2020					598,000,000
Aggregate long-term debt, maturing in 2021					0
Fair value of total debt					7,548,000,000	$ 6,515,000,000
Net proceeds from senior notes issued				$ 1,380,000,000	1,380,000,000
Repayments of debt					1,455,000,000	67,000,000	$ 590,000,000
Loss on debt extinguishment					148,000,000	0	0
Fixed-rate notes, gross principal amount					$ 5,938,000,000	$ 5,650,000,000
Weighted average interest rate					6.00%	6.40%
Additional secured debt allowed to be borrowed					$ 4,585,000,000
Capitalized interest					61,000,000	$ 45,000,000	$ 76,000,000
Letters of credit – Issued					27,000,000	32,000,000
Bakken Midstream
Debt Instrument [Line Items]
Unsecured debt issued		$ 600,000,000			600,000,000	600,000,000
Revolving credit facility - Capacity		$ 400,000,000			400,000,000	400,000,000
Revolving credit facility - Outstanding amount					$ 153,000,000	$ 110,000,000
Term Loan A facility - Term	5 years	5 years			5 years	5 years
Revolving credit facility - Term	5 years				5 years	5 years
Leverage ratio - Maximum					500.00%
Interest coverage ratio - Minimum					2.25 to 1.0
London Interbank Offered Rate (LIBOR) | Bakken Midstream | Minimum
Debt Instrument [Line Items]
Interest rate					1.10%
London Interbank Offered Rate (LIBOR) | Bakken Midstream | Maximum
Debt Instrument [Line Items]
Interest rate					2.00%
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility - Capacity					$ 4,000,000,000
Revolving credit facility - Expiration date					2020-01
Revolving credit facility – Interest rate					1.3% above the London Interbank Offered Rate
Debt instrument covenant, description					The facility contains a financial covenant that limits the amount of total borrowings on the last day of each fiscal quarter to 65% of the Corporation’s total capitalization, defined as total debt plus stockholders’ equity.
Debt instrument covenant, percentage					65.00%
Revolving credit facility - Outstanding amount					$ 0
Letters of credit – Issued					$ 0
Revolving Credit Facility | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate					1.30%
Tendered and Redeemed Notes
Debt Instrument [Line Items]
Loss on debt extinguishment					$ 148,000,000
4.30 % Senior Notes Due April 2027
Debt Instrument [Line Items]
Unsecured debt issued				$ 1,000,000,000	$ 1,000,000,000
Debt instrument maturity year				2027-04	2027-04
Debt instrument coupon rate				4.30%	4.30%
5.80 % Senior Notes Due April 2047
Debt Instrument [Line Items]
Unsecured debt issued				$ 500,000,000	$ 500,000,000
Debt instrument maturity year				2047-04	2047-04
Debt instrument coupon rate				5.80%	5.80%
8.125% Notes Due 2019
Debt Instrument [Line Items]
Debt instrument coupon rate				8.125%	8.125%
Repayments of debt				$ 1,380,000	$ 1,380,000
Notes repurchase principal amount				$ 650,000,000	$ 650,000,000
Debt instrument maturity year				2,019	2,019
7.875% Notes Due 2029
Debt Instrument [Line Items]
Debt instrument coupon rate			7.875%		7.875%
Notes repurchase principal amount			$ 196,000,000		$ 196,000,000
Debt instrument maturity year			2,029		2,029
7.300% Notes Due 2031
Debt Instrument [Line Items]
Debt instrument coupon rate			7.30%		7.30%
Notes repurchase principal amount			$ 66,000,000		$ 66,000,000
Debt instrument maturity year			2,031		2,031
1.300% Notes Due 2017
Debt Instrument [Line Items]
Debt instrument coupon rate			1.30%		1.30%
Notes repurchase principal amount			$ 300,000,000		$ 300,000,000
Debt instrument maturity year			2,017		2,017

Debt - Outstanding Letters of C

Debt - Outstanding Letters of Credit (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Disclosure [Abstract]
Committed lines	$ 1	$ 10
Uncommitted lines	187	103
Total	$ 188	$ 113

Debt - Outstanding Letters of72

Debt - Outstanding Letters of Credit (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Line Of Credit Facility [Line Items]
Contingent liabilities under letters of credit outstanding	$ 27	$ 32
Letters of credit outstanding, balance sheet liabilities	$ 161	$ 81
Committed and Uncommitted Lines
Line Of Credit Facility [Line Items]
Maturity year	2,018

Share-based Compensation - Addi

Share-based Compensation - Additional Information (Detail) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesshares
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Number of authorized common stock shares under LTIP, as amended | shares	38
Number of shares under LTIP, as amended, available for issuance of restricted common shares, performance share units and stock options | shares	10.6
Contractual term of stock options	10 years
Performance of predetermined peer companies	3 years
Minimum PSU awards payout	0.00%
Maximum PSU awards payout	200.00%
Unearned compensation expense, before income taxes due 2017	$ 66
Unearned compensation expense, before income taxes due 2018	35
Unearned compensation expense, before income taxes due 2019	$ 6
Outstanding stock options | shares	6.6
Number of stock options, exercisable | shares	5.5
Weighted average remaining contractual life for options, outstanding	3 years 7 months 6 days
Weighted average remaining contractual life for options, exercisable	2 years 7 months 6 days
Aggregated intrinsic value	$ 27
Aggregated intrinsic value for exercisable options	$ 14
Weighted average exercise price for options, exercisable | $ / shares	$ 69.71

Share-based Compensation - Shar

Share-based Compensation - Share-based Compensation Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 73	$ 97	$ 83
Income tax benefit on share-based compensation expense	28	36	31
Restricted Stock
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	45	67	62
Stock Options
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	7	5	2
Performance Share Units
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 21	$ 25	$ 19

Share-based Compensation - Sh75

Share-based Compensation - Share-based Compensation Expense (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)
Discontinued Operations
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Pre-tax share-based compensation benefit related to discontinued operations	$ 4

Share-based Compensation - Summ

Share-based Compensation - Summary of Stock-based Compensation Activity (Detail) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Exercised	(200)	(200)	(3,300)
Options - Outstanding at end of period	6,600
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Weighted average fair value on date of grant - Outstanding at beginning of period	$ 75.32
Weighted average fair value on date of grant - Granted	44.69
Weighted average fair value on date of grant - Exercised	0
Weighted average fair value on date of grant - Vested	69.57
Weighted average fair value on date of grant - Forfeited	66.98
Weighted average fair value on date of grant - Outstanding at end of period	$ 61.93	$ 75.32
Awards - Outstanding at beginning of period	2,820
Awards - Granted	1,661
Awards - Exercised	0
Awards - Vested	(833)
Awards - Forfeited	(547)
Awards - Outstanding at end of period	3,101	2,820
Vesting period from date of grant, in years	3 years
Stock Options
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Weighted average exercise price per share - Outstanding at beginning of period	$ 67.77
Weighted average exercise price per share - Granted	44.60
Weighted average exercise price per share - Exercised	53.43
Weighted average exercise price per share - Vested	0
Weighted average exercise price per share - Forfeited	55
Weighted average exercise price per share - Outstanding at end of period	$ 67.15	$ 67.77
Options - Outstanding at beginning of period	6,911
Options - Granted	824
Options - Exercised	(227)
Options - Vested	0
Options - Forfeited	(916)
Options - Outstanding at end of period	6,592	6,911
Vesting period from date of grant, in years	3 years
Performance Share Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Weighted average fair value on date of grant - Outstanding at beginning of period	$ 89.43
Weighted average fair value on date of grant - Granted	50.94
Weighted average fair value on date of grant - Exercised	0
Weighted average fair value on date of grant - Vested	111.49
Weighted average fair value on date of grant - Forfeited	65.11
Weighted average fair value on date of grant - Outstanding at end of period	$ 69.68	$ 89.43
Awards - Outstanding at beginning of period	820
Awards - Granted	447
Awards - Exercised	0
Awards - Vested	(193)
Awards - Forfeited	(59)
Awards - Outstanding at end of period	1,015	820
Vesting period from date of grant, in years	3 years

Share-based Compensation - Weig

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate the Fair Value of Stock Options (Detail) - Stock Options - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	1.47%	1.77%	1.86%
Stock price volatility	0.326%	0.312%	0.363%
Dividend yield	2.26%	1.34%	1.24%
Expected life in years	6 years	6 years	6 years
Weighted average fair value per option granted	$ 11.33	$ 21	$ 26.46

Share-based Compensation - We78

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards (Detail) - Performance Share Units - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	0.96%	1.02%	0.65%
Stock price volatility	0.329%	0.27%	0.359%
Contractual term in years	3 years	3 years	3 years
Grant date price of Hess common stock	$ 44.31	$ 74.49	$ 80.35

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Information on postretirement medical plan		Additionally, we maintain an unfunded postretirement medical plan that provides health benefits to certain qualified retirees from ages 55 through 65.
Net asset value per fund share related to short-term investment funds		$ 1
Short-term investment funds valued - NAV		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
Budgeted contributions to funded pension plans for next year		$ 52
Expense for defined contribution plans		$ 25	$ 28	$ 32
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets		50.00%
Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets		25.00%
Other Types of Investments
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets		25.00%
Scenario Forecast
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$ 61
Amortization of unrecognized net actuarial losses	$ 67
Funded and Unfunded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		$ 2,471	2,223
Net periodic benefit cost		62	94	53
Amortization of unrecognized net actuarial losses		60	75	$ 32
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		$ 203	$ 196

Retirement Plans - Change in Be

Retirement Plans - Change in Benefit Obligation, Fair Value of Plan Assets, and Funded Status of Pension Plans and Postretirement Medical Plan (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Change In Fair Value of Plan Assets
Beginning balance	$ 2,206
Ending balance	2,284	$ 2,206
Funded Pension Plans
Change In Benefit Obligation
Beginning balance	2,321	2,450
Service cost	44	51
Interest cost	98	93
Actuarial loss (gain)	162	(156)
Benefit payments	(132)	(85)
Plan curtailments	(2)	(4)
Special termination benefits	1	1
Assumption of HOVENSA pension plan	151	0
Foreign currency exchange rate changes	(83)	(29)
Ending balance	2,560	2,321	$ 2,450
Change In Fair Value of Plan Assets
Beginning balance	2,206	2,251
Actual return on plan assets	153	28
Employer contributions	26	44
Benefit payments	(132)	(85)
Assumption of HOVENSA pension plan	126	0
Foreign currency exchange rate changes	(95)	(32)
Ending balance	2,284	2,206	2,251
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	(276)	(115)
Unrecognized Net Actuarial (Gains) Losses	895	775
Unfunded Pension Plan
Change In Benefit Obligation
Beginning balance	259	278
Service cost	16	16
Interest cost	9	9
Actuarial loss (gain)	(5)	(2)
Benefit payments	(23)	(42)
Plan curtailments	0	0
Special termination benefits	0	0
Assumption of HOVENSA pension plan	0	0
Foreign currency exchange rate changes	0	0
Ending balance	256	259	278
Change In Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	23	42
Benefit payments	(23)	(42)
Assumption of HOVENSA pension plan	0	0
Foreign currency exchange rate changes	0	0
Ending balance	0	0	0
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	(256)	(259)
Unrecognized Net Actuarial (Gains) Losses	93	105
Postretirement Medical Plan
Change In Benefit Obligation
Beginning balance	98	94
Service cost	4	4	4
Interest cost	3	3	3
Actuarial loss (gain)	(13)	5
Benefit payments	(8)	(8)
Plan curtailments	0	0
Special termination benefits	0	0
Assumption of HOVENSA pension plan	0	0
Foreign currency exchange rate changes	0	0
Ending balance	84	98	94
Change In Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	8	8
Benefit payments	(8)	(8)
Assumption of HOVENSA pension plan	0	0
Foreign currency exchange rate changes	0	0
Ending balance	0	0	$ 0
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	(84)	(98)
Unrecognized Net Actuarial (Gains) Losses	$ (13)	$ 0

Retirement Plans - Change in 81

Retirement Plans - Change in Benefit Obligation, Fair Value of Plan Assets, and Funded Status of Pension Plans and Postretirement Medical Plan (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Lump-sum settlement payment included in Benefit payments	$ 65	$ 41
Change in Discount Rate
Defined Benefit Plan Disclosure [Line Items]
Actuarial loss (gain) resulted from a change	$ 175

Retirement Plans - Amounts Reco

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	$ (276)	$ (115)
Accumulated other comprehensive (gain) loss, pre-tax	895	775
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	(256)	(259)
Accumulated other comprehensive (gain) loss, pre-tax	93	105
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	(84)	(98)
Accumulated other comprehensive (gain) loss, pre-tax	$ (13)	$ 0

Retirement Plans - Amounts Re83

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Compensation And Retirement Disclosure [Abstract]
Accumulated other comprehensive (gain) loss related to retirement plans, after-tax	$ 660	$ 563

Retirement Plans - Components o

Retirement Plans - Components of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 60	$ 67	$ 57
Interest cost	107	102	100
Expected return on plan assets	(166)	(168)	(161)
Amortization of unrecognized net actuarial losses	60	75	32
Settlement loss	0	17	24
Special termination benefit recognized	1	1	1
Net Periodic Benefit Cost	62	94	53
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	4
Interest cost	3	3	3
Expected return on plan assets	0	0	0
Amortization of unrecognized net actuarial losses	0	0	0
Settlement loss	0	0	0
Special termination benefit recognized	0	0	0
Net Periodic Benefit Cost	$ 7	$ 7	$ 7

Retirement Plans - Actuarial As

Retirement Plans - Actuarial Assumptions Used for Pension Plans & Postretirement Medical Plan (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Plans
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.70%	4.10%	3.80%
Rate of compensation increase	4.60%	4.50%	5.00%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31
Discount rate	4.10%	3.80%	4.60%
Expected return on plan assets	7.40%	7.50%	7.50%
Rate of compensation increase	4.50%	5.00%	4.40%
Postretirement Medical Plan
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.50%	3.50%	3.10%
Initial health care trend rate	7.70%	6.70%	6.80%
Ultimate trend rate	4.50%	4.50%	4.50%
Year in which ultimate trend rate is reached	2,038	2,038	2,029

Retirement Plans - Fair Value o

Retirement Plans - Fair Value of Financial Assets of Funded Pension Plans (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 2,284	$ 2,206
Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	88	34
U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	550	556
International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	435	425
Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	199	219
Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	202	213
Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	38	7
Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	166	176
Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	187	157
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	209	216
Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	126	122
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	62	64
Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	22	17
Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	732	729
Level 1 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	9	0
Level 1 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	550	556
Level 1 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	160	159
Level 1 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	2	2
Level 1 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	1	0
Level 1 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	10	12
Level 1 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	1,163	1,084
Level 2 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	79	34
Level 2 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	275	266
Level 2 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	197	217
Level 2 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	202	213
Level 2 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	38	6
Level 2 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	164	174
Level 2 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	186	157
Level 2 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	22	17
Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	389	393
Level 3 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	1
Level 3 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	2	2
Level 3 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	209	216
Level 3 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	126	122
Level 3 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	52	52
Level 3 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 0	$ 0

Retirement Plans - Changes in F

Retirement Plans - Changes in Financial Assets that are Measured at Fair Value Based on Level 3 Inputs that are held by Institutional Funds (Detail) - Level 3 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	$ 393	$ 457
Actual return on plan assets	5	22
Purchases, sales or other settlements	(9)	(86)
Net transfers in (out) of Level 3	0	0
Ending balance	389	393
Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	3	2
Actual return on plan assets	0	0
Purchases, sales or other settlements	(1)	1
Net transfers in (out) of Level 3	0	0
Ending balance	2	3
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	216	302
Actual return on plan assets	(7)	(5)
Purchases, sales or other settlements	0	(81)
Net transfers in (out) of Level 3	0	0
Ending balance	209	216
Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	122	105
Actual return on plan assets	5	18
Purchases, sales or other settlements	(1)	(1)
Net transfers in (out) of Level 3	0	0
Ending balance	126	122
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	52	48
Actual return on plan assets	7	9
Purchases, sales or other settlements	(7)	(5)
Net transfers in (out) of Level 3	0	0
Ending balance	$ 52	$ 52

Retirement Plans - Estimated Fu

Retirement Plans - Estimated Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan (Detail) $ in Millions	Dec. 31, 2016USD ($)
Compensation And Retirement Disclosure [Abstract]
2,017	$ 138
2,018	123
2,019	133
2,020	135
2,021	136
Years 2022 to 2026	$ 725

Exit and Disposal Costs - Addit

Exit and Disposal Costs - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restructuring And Related Activities [Abstract]
Severance expense	$ 55	$ 13	$ 76
Accrued severance costs paid	52	57	170
Other exit related costs		15	65
Accrued facility and other exit costs paid	2	21	$ 158
Accrued severance costs	36	33
Restructuring Reserve	$ 17	$ 19
Expected period for all payments for severance cost	2,017
Accrued liabilities of exit costs to be settled in next several years	$ 14

Income Taxes - Components of In

Income Taxes - Components of Income Tax Provision (Benefit) for Continuing Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
United States - Federal, Current income tax expense (benefit)	$ (27)	$ (7)	$ (1)
United States - Federal, Deferred income taxes and other accruals expense (benefit)	1,948	(995)	156
United States - State, Current & Deferred income taxes and other accruals expense (benefit)	23	(61)	57
United States, Current & Deferred income taxes and other accruals expense (benefit)	1,944	(1,063)	212
Foreign, Current income tax expense (benefit)	36	4	453
Foreign, Deferred income taxes and other accruals expense (benefit)	235	(231)	79
Foreign, Current & Deferred income taxes and other accruals expense (benefit)	271	(227)	532
Provision (benefit) for income taxes - before adjustments due to income tax law changes	2,215	(1,290)	744
Adjustment of deferred taxes for foreign income tax law changes	7	(9)
Total Provision (Benefit) For Income Taxes	$ 2,222	$ (1,299)	$ 744

Income Taxes - Components of 91

Income Taxes - Components of Income Tax Provision (Benefit) for Continuing Operations (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Income Tax Expense Benefit Continuing Operations [Line Items]
Valuation allowance against net deferred tax assets	$ 5,450	$ 1,579
U.S., Denmark and Malaysia
Income Tax Expense Benefit Continuing Operations [Line Items]
Valuation allowance against net deferred tax assets	$ 3,749	$ 2,683

Income Taxes - Income (Loss) Fr

Income Taxes - Income (Loss) From Continuing Operations Before Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income (Loss) From Continuing Operations Before Income Taxes - United States	$ (2,431)	$ (2,728)	$ 676
Income (Loss) From Continuing Operations Before Income Taxes - Foreign	(1,423)	(1,530)	1,760
Income (Loss) from Continuing Operations Before Income Taxes	$ (3,854)	$ (4,258)	$ 2,436

Income Taxes - Components of De

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Liabilities
Property, plant and equipment and investments	$ (3,810)	$ (3,743)
Other	(255)	(257)
Total Deferred Tax Liabilities	(4,065)	(4,000)
Deferred Tax Assets
Net operating loss carryforwards	5,767	3,852
Tax credit carryforwards	164	188
Property, plant and equipment and investments	834	981
Accrued compensation, deferred credits and other liabilities	526	492
Asset retirement obligations	1,077	1,220
Other	62	165
Total Deferred Tax Assets	8,430	6,898
Valuation allowances	(5,450)	(1,579)
Total deferred tax assets, net of valuation allowances	2,980	5,319
Net Deferred Tax Liabilities	$ (1,085)
Net Deferred Tax Assets		$ 1,319

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Income Tax Examination [Line Items]
Gross deferred tax asset related to net operating loss carryforwards	$ 5,767	$ 3,852
Gross deferred tax asset related to foreign net operating loss carryforwards	$ 2,610
Year in which foreign net operating loss carryforwards begin to expire	2,024
Gross deferred tax asset related to net U.S. federal operating loss carryforwards	$ 2,766
Year in which U.S. federal net operating loss carryforwards begin to expire	2,021
Gross deferred tax asset related to net operating loss carryforwards for various U.S. states	$ 391
Year in which various U.S. states net operating loss carryforwards begin to expire	2,017
Deferred tax asset related to foreign net operating loss carryforwards, net of valuation allowance	$ 1,468
Deferred tax asset related to U.S. federal net operating loss carryforwards, net of valuation allowance	39
Alternative minimum tax credit carryforwards	77
Other business credit carryforwards	6
Deferred tax asset related to business credit carryforwards, net of valuation allowance	1
Foreign tax credit carryforwards - Before valuation allowance	$ 81
Year in which foreign tax credit carryforwards begin to expire	2,017
Valuation allowance against net deferred tax assets	$ 5,450	1,579
Additional valuation allowance against net deferred tax assets during the year	$ 1,066
Period of cumulative loss incurred	3 years
Unrecognized tax benefits that would impact effective income tax rate	$ 233
Unrecognized tax benefits decrease reasonably possible	85
Accrued interest and penalties	29	74
Undistributed earnings from foreign subsidiaries expected to be indefinitely reinvested in foreign operations	7,600
U.S., Denmark and Malaysia
Income Tax Examination [Line Items]
Valuation allowance against net deferred tax assets	$ 3,749	$ 2,683

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities, Net (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Deferred income taxes	$ 59	$ 2,653
Deferred income taxes (long-term liability)	(1,144)	(1,334)
Net Deferred Tax Liabilities	$ (1,085)
Net Deferred Tax Assets		$ 1,319

Income Taxes - Effective Income

Income Taxes - Effective Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
U.S. statutory rate	35.00%	35.00%	35.00%
Effect of foreign operations	4.60%	5.90%	0.70%
State income taxes, net of Federal income tax	1.90%	0.90%	1.50%
Change in enacted tax laws	(0.20%)	0.20%	0.00%
Gains on asset sales, net	(0.00%)	(0.20%)	(8.30%)
Impairment	(2.10%)	(12.20%)	0.00%
Valuation allowance against previously benefitted deferred tax assets	(97.30%)	(3.10%)	0.60%
Benefit of legal entity restructuring	0.00%	3.50%	0.00%
Other	0.40%	0.50%	1.00%
Total	(57.70%)	30.50%	30.50%

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Balance at January 1	$ 604	$ 603
Additions based on tax positions taken in the current year	19	19
Additions based on tax positions of prior years	113	29
Reductions based on tax positions of prior years	(274)	(31)
Reductions due to settlements with taxing authorities	(27)	(12)
Reductions due to lapses in statutes of limitation	(11)	(4)
Balance at December 31	$ 424	$ 604

Outstanding and Weighted Aver98

Outstanding and Weighted Average Common Shares - Changes in Outstanding Common Shares (Detail) - shares	12 Months Ended			46 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Earnings Per Share [Abstract]
Balance at January 1	286,000,000	285,800,000	325,300,000
Shares issued	28,750,000	0	0
Activity related to restricted stock awards, net	1,100,000	800,000	600,000
Stock options exercised	200,000	200,000	3,300,000
PSU vested	400,000	600,000	0
Shares repurchased	0	(1,450,000)	(43,350,000)	(64,110,000)
Balance at December 31	316,500,000	286,000,000	285,800,000	316,500,000

Outstanding and Weighted Aver99

Outstanding and Weighted Average Common Shares - Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Income (loss) from continuing operations, net of income taxes	$ (6,076)	$ (2,959)	$ 1,692
Less: Net income (loss) attributable to noncontrolling interests	56	49	0
Net income (loss) from continuing operations attributable to Hess Corporation	(6,132)	(3,008)	1,692
Less: Preferred stock dividends	41	0	0
Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders	(6,173)	(3,008)	1,692
Income (loss) from discontinued operations, net of income taxes	0	(48)	682
Less: Net income (loss) attributable to noncontrolling interests	0	0	57
Income (Loss) from Discontinued Operations Attributable to Hess Corporation	0	(48)	625
Net Income (Loss) Applicable to Hess Corporation Common Stockholders	$ (6,173)	$ (3,056)	$ 2,317
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Basic	309.9	283.6	303.7
Shares outstanding – Diluted	309.9	283.6	307.7
Net Income (Loss) Attributable to Hess Corporation per Common Share – Basic:
Continuing operations	$ (19.92)	$ (10.61)	$ 5.57
Discontinued operations	0	(0.17)	2.06
Net Income (Loss) Per Common Share	(19.92)	(10.78)	7.63
Net Income (Loss) Attributable to Hess Corporation per Common Share – Diluted:
Continuing operations	(19.92)	(10.61)	5.50
Discontinued operations	0	(0.17)	2.03
Net Income (Loss) Per Common Share	$ (19.92)	$ (10.78)	$ 7.53
Restricted Stock
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0	0	1.5
Stock Options
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0	0	1.8
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0	0	0.7
Mandatory Convertible Preferred Stock
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0	0	0

Outstanding and Weighted Ave100

Outstanding and Weighted Average Common Shares - Antidilutive Shares Excluded from Computation of Diluted Shares (Detail) - shares shares in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Common Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	3.3	2.9	0
Stock Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	6.9	6.9	1.4
Performance Share Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	0.9	1	0
Common Shares from Conversion of Preferred Stocks
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	11.2	0	0

Outstanding and Weighted Ave101

Outstanding and Weighted Average Common Shares - Additional Information (Detail) - $ / shares	3 Months Ended												12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Earnings Per Share [Abstract]
Cash dividends on common stock	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 1	$ 1	$ 1

Share Repurchase Plan - Additio

Share Repurchase Plan - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2016	May 31, 2014	Dec. 31, 2013
Equity [Abstract]
Repurchase of outstanding common stock		$ 6,500	$ 4,000
Additional amount of common stock that may be repurchased	$ 1,150

Share Repurchase Plan - Schedul

Share Repurchase Plan - Schedule of Share Repurchases Under Share Repurchase Plan - (Detail) - USD ($) shares in Thousands, $ in Millions	12 Months Ended			46 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Equity [Abstract]
Total cost of shares repurchased	$ 0	$ 91	$ 3,722	$ 5,351
Total number of shares repurchased	0	1,450	43,350	64,110

Supplementary Cash Flow Info104

Supplementary Cash Flow Information (Detail) - USD ($) $ in Millions	Jul. 01, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows From Operating Activities
Interest paid		$ (338)	$ (331)	$ (326)
Net income taxes (paid) refunded		132	(140)	(455)
Cash Flows From Investing Activities
Capital expenditures incurred - E&P		(1,645)	(3,753)	(4,920)
(Increase) decrease in related liabilities – E&P		(334)	(203)	53
Additions to property, plant and equipment - E&P		(1,979)	(3,956)	(4,867)
Capital expenditures incurred - Bakken Midstream		(276)	(296)	(301)
(Increase) decrease in related liabilities – Bakken Midstream		4	(69)	(46)
Additions to property, plant and equipment - Bakken Midstream		(272)	(365)	(347)
Cash Flows From Financing Activities
Contribution from formation of Bakken Midstream joint venture	$ 2,628	0	2,628	0
Distributions to partner in Bakken Midstream joint venture		(23)	(332)	0
Noncontrolling interests, net related to Continuing operations		(23)	2,296	0
Significant Non-Cash Transactions
Increase in debt due to construction of a floating production system - Tubular Bells Field		$ 0	$ 0	$ 68

Leased Assets - Future Minimum

Leased Assets - Future Minimum Rental Payments (Detail) $ in Millions	Dec. 31, 2016USD ($)
Leases [Abstract]
2,017	$ 376
2,018	375
2,019	351
2,020	124
2,021	67
Remaining years	338
Total Minimum Lease Payments	1,631
Less: Income from subleases	78
Net Minimum Lease Payments	$ 1,553

Leased Assets - Rental Expense

Leased Assets - Rental Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Leases [Abstract]
Total rental expense	$ 106	$ 167	$ 248
Less: Income from subleases	5	10	17
Net Rental Expense	$ 101	$ 157	$ 231

Guarantees, Contingencies an107

Guarantees, Contingencies and Commitments - Additional Information (Detail) - USD ($)	Jan. 18, 2017	Mar. 04, 2016	Apr. 30, 2014	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Contingent liabilities under letters of credit outstanding					$ 27,000,000	$ 32,000,000
Estimated remediation cost related to Lower Passaic River in New Jersey		$ 1,380,000,000	$ 1,700,000,000
N Y
Loss Contingencies [Line Items]
Estimated remediation cost related to Lower Passaic River in New Jersey				$ 506,000,000
Legacy conventional North Dakota Assets | Subsequent Event
Loss Contingencies [Line Items]
Penalty assessed under consent decree	$ 922,000
Initial penalty payment under consent decree	$ 55,000

Guarantees, Contingencies an108

Guarantees, Contingencies and Commitments - Schedule of Unconditional Purchase Obligations and Commitments (Detail) $ in Millions	Dec. 31, 2016USD ($)
Capital Expenditures
Loss Contingencies [Line Items]
Total	$ 708
2,017	632
2018 and 2019	76
2020 and 2021	0
Thereafter	0
Operating Expenses
Loss Contingencies [Line Items]
Total	497
2,017	393
2018 and 2019	76
2020 and 2021	18
Thereafter	10
Transportation and Related Contracts
Loss Contingencies [Line Items]
Total	1,560
2,017	182
2018 and 2019	457
2020 and 2021	433
Thereafter	$ 488

Segment Information - Additiona

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	2

Segment Information - Financial

Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating Revenues - Third parties	$ 4,762	$ 6,636	$ 10,737
Intersegment Revenues	0	0	0
Operating Revenues	4,762	6,636	10,737
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	(6,132)	(3,008)	1,692
Interest Expense	338	341	323
Depreciation, Depletion and Amortization	3,244	3,955	3,224
Impairment	67	1,616	0
Provision (Benefit) for Income Taxes	2,222	(1,299)	744
Investment in Affiliates	146	154
Identifiable Assets	28,621	34,157
Capital Expenditures	1,921	4,049	5,274
Exploration and Production
Segment Reporting Information [Line Items]
Operating Revenues - Third parties	4,762	6,636	10,737
Intersegment Revenues	0	0	0
Operating Revenues	4,762	6,636	10,737
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	(4,963)	(2,717)	2,086
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	3,132	3,852	3,140
Impairment	0	1,616
Provision (Benefit) for Income Taxes	1,588	(1,111)	989
Investment in Affiliates	146	154
Identifiable Assets	23,102	28,863
Capital Expenditures	1,645	3,753	4,920
Bakken Midstream
Segment Reporting Information [Line Items]
Operating Revenues - Third parties	0	0	0
Intersegment Revenues	510	564	319
Operating Revenues	510	564	319
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	41	86	10
Interest Expense	19	10	2
Depreciation, Depletion and Amortization	102	88	70
Impairment	67	0
Provision (Benefit) for Income Taxes	25	52	7
Investment in Affiliates	0	0
Identifiable Assets	2,919	2,754
Capital Expenditures	276	296	301
Corporate, Interest and Other
Segment Reporting Information [Line Items]
Operating Revenues - Third parties	0	0	0
Intersegment Revenues	0	0	0
Operating Revenues	0	0	0
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	(1,210)	(377)	(404)
Interest Expense	319	331	321
Depreciation, Depletion and Amortization	10	15	14
Impairment	0	0
Provision (Benefit) for Income Taxes	609	(240)	(252)
Investment in Affiliates	0	0
Identifiable Assets	2,600	2,540
Capital Expenditures	0	0	53
Eliminations
Segment Reporting Information [Line Items]
Operating Revenues - Third parties	0	0	0
Intersegment Revenues	(510)	(564)	(319)
Operating Revenues	(510)	(564)	(319)
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	0	0	0
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	0	0	0
Impairment	0	0
Provision (Benefit) for Income Taxes	0	0	0
Investment in Affiliates	0	0
Identifiable Assets	0	0
Capital Expenditures	$ 0	$ 0	$ 0

Segment Information - Financ111

Segment Information - Financial Information by Major Geographic Area (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating revenues		$ 4,762	$ 6,636	$ 10,737
Net income (loss) from continuing operations attributable to Hess Corporation		(6,132)	(3,008)	1,692
Depreciation, depletion and amortization		3,244	3,955	3,224
Impairment		67	1,616	0
Provision (benefit) for income taxes		2,222	(1,299)	744
Identifiable assets		28,621	34,157
Property, plant and equipment, net	[1]	23,595	26,352
Capital expenditures		1,921	4,049	5,274
Corporate, Interest and Other
Segment Reporting Information [Line Items]
Operating revenues		0	0	0
Net income (loss) from continuing operations attributable to Hess Corporation		(1,210)	(377)	(404)
Depreciation, depletion and amortization		10	15	14
Impairment		0	0
Provision (benefit) for income taxes		609	(240)	(252)
Identifiable assets		2,600	2,540
Property, plant and equipment, net	[1]	47	121
Capital expenditures		0	0	53
United States
Segment Reporting Information [Line Items]
Operating revenues		3,085	4,150	6,270
Net income (loss) from continuing operations attributable to Hess Corporation		(2,353)	(1,834)	654
Depreciation, depletion and amortization		2,133	2,449	1,751
Impairment		67	986
Provision (benefit) for income taxes		411	(522)	446
Identifiable assets		16,096	18,365
Property, plant and equipment, net	[1]	14,596	15,729
Capital expenditures		1,400	2,727	3,467
Europe
Segment Reporting Information [Line Items]
Operating revenues		610	870	1,557
Net income (loss) from continuing operations attributable to Hess Corporation		(439)	(408)	226
Depreciation, depletion and amortization		502	635	683
Impairment		0	279
Provision (benefit) for income taxes		243	(84)	91
Identifiable assets		5,180	6,207
Property, plant and equipment, net	[1]	4,907	5,300
Capital expenditures		59	297	524
Africa
Segment Reporting Information [Line Items]
Operating revenues		601	945	2,002
Net income (loss) from continuing operations attributable to Hess Corporation		(355)	(274)	545
Depreciation, depletion and amortization		375	539	487
Impairment		0	100
Provision (benefit) for income taxes		244	(48)	435
Identifiable assets		1,507	2,178
Property, plant and equipment, net	[1]	1,266	1,682
Capital expenditures		10	160	399
Asia and Other Countries
Segment Reporting Information [Line Items]
Operating revenues		466	671	908
Net income (loss) from continuing operations attributable to Hess Corporation		(1,775)	(115)	671
Depreciation, depletion and amortization		224	317	289
Impairment		0	251
Provision (benefit) for income taxes		715	(405)	24
Identifiable assets		3,238	4,867
Property, plant and equipment, net	[1]	2,779	3,520
Capital expenditures		$ 452	$ 865	$ 831
[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Segment Information - Financ112

Segment Information - Financial Information by Major Geographic Area (Parenthetical) (Detail) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Property, plant and equipment, net	[1]	$ 23,595	$ 26,352
Norway
Segment Reporting Information [Line Items]
Property, plant and equipment, net		$ 3,893	$ 4,108
[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016 (2015: $4,108 million).

Related Party Transactions - Re

Related Party Transactions - Related Party Transactions (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
WilcoHess
Related Party Transaction [Line Items]
Sales	$ 0	$ 0	$ 211
HOVENSA
Related Party Transaction [Line Items]
Sales	$ 0	$ 0	$ 31

Related Party Transactions -114

Related Party Transactions - Related Party Transactions (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended
	Jan. 31, 2014	Dec. 31, 2014
Related Party Transactions [Abstract]
Percentage of interest in WilcoHess acquired for preparation of its subsequent sale with retail business	56.00%	56.00%
Cost of acquiring additional ownership interest in WilcoHess	$ 290

Financial Risk Management Ac115

Financial Risk Management Activities - Gross Notional Amounts of Derivative Contracts Outstanding (Detail) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Foreign Exchange
Derivative [Line Items]
Outstanding gross notional amount	$ 785,000,000	$ 967,000,000
Interest Rate Swaps
Derivative [Line Items]
Outstanding gross notional amount	$ 350,000,000	$ 1,300,000,000

Financial Risk Management Ac116

Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Accounts Receivable
Derivatives Fair Value [Line Items]
ASSETS - Gross fair value of derivative contracts	$ 9	$ 22
ASSETS – Master netting arrangements	(1)	(3)
ASSETS - Net fair value of derivative contracts	8	19
Accounts Receivable | Designated As Hedging Instrument
Derivatives Fair Value [Line Items]
ASSETS - Gross fair value of derivative contracts	0	3
Accounts Receivable | Designated As Hedging Instrument | Interest Rate Contract
Derivatives Fair Value [Line Items]
ASSETS - Gross fair value of derivative contracts	0	3
Accounts Receivable | Derivative Contracts Not Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
ASSETS - Gross fair value of derivative contracts	9	19
Accounts Receivable | Derivative Contracts Not Designated as Hedging Instruments | Foreign Exchange
Derivatives Fair Value [Line Items]
ASSETS - Gross fair value of derivative contracts	9	19
Accounts Payable
Derivatives Fair Value [Line Items]
LIABILITIES - Gross fair value of derivative contracts	(1)	(3)
LIABILITIES – Master netting arrangements	1	3
LIABILITIES - Net fair value of derivative contracts	0	0
Accounts Payable | Designated As Hedging Instrument
Derivatives Fair Value [Line Items]
LIABILITIES - Gross fair value of derivative contracts	0	0
Accounts Payable | Designated As Hedging Instrument | Interest Rate Contract
Derivatives Fair Value [Line Items]
LIABILITIES - Gross fair value of derivative contracts	0	0
Accounts Payable | Derivative Contracts Not Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
LIABILITIES - Gross fair value of derivative contracts	(1)	(3)
Accounts Payable | Derivative Contracts Not Designated as Hedging Instruments | Foreign Exchange
Derivatives Fair Value [Line Items]
LIABILITIES - Gross fair value of derivative contracts	$ (1)	$ (3)

Financial Risk Management Ac117

Financial Risk Management Activities - Corporate Financial Risk Management Activities - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Commodity
Derivative Instruments Gain Loss [Line Items]
Crude oil price hedging contracts increased (decreased) E&P sales and other operating revenues by this amount, pre-tax		$ 126,000,000	$ 193,000,000
Other operating revenue, losses associated with changes in time value of crude oil collars		(48,000,000)
Commodity | Crude Oil
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	$ 0
Interest Rate Swaps
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	350,000,000	1,300,000,000
Amount of cash proceeds received from settled interest rate swaps	5,000,000	41,000,000
Unrealized change in fair value of interest rate swaps - increase/(decrease)	6,000,000	4,000,000	1,000,000
Foreign Exchange
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	785,000,000	967,000,000
Total foreign exchange gains and (losses) reported in Other, net in Revenues and Non-Operating Income in the Statement of Consolidated Income	26,000,000	(21,000,000)	(43,000,000)
Gain (Loss) on foreign exchange contracts not designated as hedging instruments	62,000,000	98,000,000	117,000,000
After tax foreign currency translation adjustments included in Accumulated other comprehensive income (loss)	56,000,000	(344,000,000)	$ (756,000,000)
Accumulated cumulative currency translation adjustment	$ (1,045,000,000)	$ (1,101,000,000)

Financial Risk Management Ac118

Financial Risk Management Activities - Credit Risk - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Outstanding letters of credit	$ 188	$ 113
Integrated Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	37.00%
Independent E&P Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	19.00%
National Oil Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	16.00%
Storage and Transportation Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	10.00%
Refining and Marketing Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	7.00%
Others [Member]
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	11.00%

Schedule - VALUATION AND QUALIF

Schedule - VALUATION AND QUALIFYING ACCOUNTS (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Losses on Receivables
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning Balance	$ 43	$ 13	$ 27
Charged to Costs and Expenses	5	32	0
Charged to Other Accounts	0	0	0
Deductions from Reserves	40	2	14
Ending Balance	8	43	13
Deferred Income Tax Valuation
Valuation and Qualifying Accounts Disclosure [Line Items]
Beginning Balance	1,578	1,416	1,519
Charged to Costs and Expenses	3,962	280	142
Charged to Other Accounts	0	0	(1)
Deductions from Reserves	90	118	244
Ending Balance	$ 5,450	$ 1,578	$ 1,416