View Filing Data

Less: Reserves for depreciation, depletion, amortization and lease impairment

46,907

46,826

23,312

20,474

Property, plant and equipment — net

^[1]

23,595

26,352

Goodwill

375

Deferred income taxes

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

Current maturities of long-term debt

112

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)

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 (Parenthetical) - $ / shares	12 Months Ended
Consolidated Balance Sheet (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1.00
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	$ 1.00	$ 1.00
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	316,523,200	286,045,586

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	0.00	(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	$ 1.00	$ 1.00	$ 1.00

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 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 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 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, which requires debt issuance costs to be presented in the balance sheet as a direct reduction to the associated debt liability. The Consolidated Balance Sheet at December 31, 2015 has been recast to reduce Other assets and Long-term debt by $38 million. In 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements – Going Concern. This ASU requires that management evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued. This ASU is effective for us beginning in the fourth quarter of 2016. The adoption of ASU 2014-15 did not have an impact on our consolidated financial statements. 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 CO₂ for tertiary recovery are expensed as incurred. The costs of exploratory wells that find oil and gas reserves are capitalized pending determination of whether proved reserves have been found. Exploratory drilling costs remain capitalized after drilling is completed if (1) the well has found a sufficient quantity of reserves to justify completion as a producing well and (2) sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If either of those criteria is not met, or if there is substantial doubt about the economic or operational viability of a project, the capitalized well costs are charged to expense. Indicators of sufficient progress in assessing reserves and the economic and operating viability of a project include commitment of project personnel, active negotiations for sales contracts with customers, negotiations with governments, operators and contractors, firm plans for additional drilling and other factors. Depreciation, Depletion and Amortization: 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 or when events or circumstances indicate that the carrying amount of the goodwill may not be recoverable based on a two-step process. In step one of the impairment test, the fair value of a reporting unit is compared with its carrying amount, including goodwill. If the fair value of the reporting unit exceeds its carrying value, goodwill is not impaired. If the carrying value of the reporting unit exceeds its fair value, we perform step two to determine possible impairment by comparing the implied fair value of goodwill with the carrying amount. If the implied fair value of goodwill is less than its carrying amount, an impairment loss would be recorded. In addition to our annual test, we also performed separate goodwill impairment tests at December 31, 2015 and June 30, 2015. See 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. Our policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized currently in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges) or hedges of firm commitments (fair value hedges). The effective portion of changes in fair value of derivatives that are designated as cash flow hedges is recorded as a component of other comprehensive income (loss) while the ineffective portion of the changes in fair value is recorded currently in earnings. Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings. Changes in fair value of derivatives designated as fair value hedges are recognized currently in earnings. The change in fair value of the related hedged commitment is recorded as an adjustment to its carrying amount and recognized currently in earnings. Fair Value Measurements: 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, as a new ASC Topic, ASC 842. The new standard will require assets and liabilities to be reported on the balance sheet for all leases with lease terms greater than one year, including leases currently treated as operating leases under the existing standard. This ASU is effective for us beginning in the first quarter of 2019, with early adoption permitted. We are currently assessing the impact of the ASU on our consolidated financial statements. In March 2016, the FASB issued Accounting Standards Update (ASU) 2016-09, Improvements to Employee Share-Based Payment Accounting. This ASU makes changes to various provisions associated with share-based accounting, including provisions affecting the accounting for income taxes, the accounting for forfeitures, and the consideration of net settlement provisions on the balance sheet classification of the share-based award. This ASU is effective for us beginning in the first quarter of 2017. The adoption of ASU 2016 – 09 is not expected to have a material impact on our consolidated financial statements. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared to the current "incurred loss" model. This ASU is effective for us beginning in the first quarter of 2020, with early adoption permitted from the first quarter of 2019. We are currently assessing the impact of the ASU on our consolidated financial statements. In October 2016, the FASB issued ASU 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory. This ASU will require the recognition of income tax consequences from intra-entity transfer of assets other than inventory when the transfer occurs. This ASU is effective for us beginning in the first quarter of 2018, with early adoption permitted. We plan to adopt ASU 2016-16 in the first quarter of 2017, which is not expected to have a material impact on our consolidated financial statements. In January 2017, the FASB issued ASU 2017-01, Business Combinations – Clarifying the Definition of a Business. This ASU provides a screen that excludes an integrated set of activities and assets from the definition of a business if the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or group of similar identifiable assets. This ASU also clarifies that an integrated set of activities and assets must include (at a minimum), an input and a substantive process that together significantly contribute to the ability to create output to be considered a business. This ASU is effective for us beginning in the first quarter of 2018, with early application permitted. We are currently assessing the impact of the ASU on our consolidated financial statements. In January 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment. This ASU modifies the concept of goodwill impairment from a condition that exists when the carrying amount of goodwill exceeds its implied fair value to the condition that exists when the carrying amount of the reporting unit exceeds its fair value. Thus, an entity should recognize an impairment charge for the amount by which the carrying amount of a reporting unit exceeds its fair value. The impairment charge would be limited by the amount of goodwill allocated to the reporting unit. This ASU removes the requirement to determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if the reporting unit had been acquired in a business combination. This ASU is effective for us beginning in the first quarter of 2020, with early adoption permitted. We are currently assessing the impact of the ASU on our consolidated financial statements. 1

Common and Preferred Stock Issuance	12 Months Ended
Common and Preferred Stock Issuance	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.

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

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Property Plant And Equipment [Abstract]

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

12 Months Ended

Dec. 31, 2016

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

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 for further information.

Impairment	12 Months Ended
Impairment	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), we performed impairment tests on the Offshore and Onshore reporting units prior to creation of the Bakken Midstream segment in accordance with accounting standards for goodwill. No impairment resulted from this assessment. In addition, we performed separate impairment tests at June 30, 2015, on the allocated goodwill to the Bakken Midstream segment and Onshore reporting unit of the E&P segment following the creation of the Bakken Midstream segment. No impairment existed for the Bakken Midstream segment, but goodwill allocated to the Onshore reporting unit of $385 million did not pass the impairment test, and as a result was reduced to its implied fair value of zero based on a hypothetical purchase price allocation as stipulated in the accounting standards. In addition, as part of the further deterioration in crude oil prices in the fourth quarter of 2015, we determined goodwill allocated to the Offshore reporting unit of $1,098 million did not pass the impairment test, and as a result was reduced to its implied fair value of zero based on a hypothetical purchase price allocation as stipulated in the accounting standards. Fair value of our Onshore and Offshore reporting units were determined using multiple valuation techniques, including projected discounted cash flows of producing assets and known development projects. The determination of projected discounted cash flows depended on estimates of oil and gas reserves, future prices, operating costs, capital expenditures, discount rate and timing of future net cash flows. We also considered the relative market valuation of similar peer companies using market multiples, and other observable market data, in assessing fair value of each reporting unit. The valuation methodologies used represent Level 3 measurements. 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	12 Months Ended
Bakken Midstream Joint Venture	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, while the carrying amount of GIP’s equity is included as Noncontrolling interests in the 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	12 Months Ended
Dispositions	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

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 and the Statement of Consolidated Cash Flows for all periods presented.

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.

The entire disclosure related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

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Asset Retirement Obligation Disclosure [Abstract]

HOVENSA LLC	12 Months Ended
HOVENSA LLC	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

12 Months Ended

Dec. 31, 2016

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, was $102 million at December 31, 2016 and $79 million at December 31, 2015.

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 aggregate total debt maturing during the next five years is as follows (in millions): 2017: $112; 2018: $123; 2019: $448; 2020: $598 and 2021: $-.

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

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)Includes benefit related to discontinued operations of $4 million for 2014.

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.

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

Compensation And Retirement Disclosure [Abstract]

Retirement Plans

12 Months Ended

Dec. 31, 2016

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	12 Months Ended
Exit and Disposal Costs	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 realignment of our organizational structure communicated in November 2016. Severance charges in 2015 and 2014 resulted from a divestiture program announced in 2013. Severance charges were based on amounts incurred under ongoing severance arrangements or other statutory requirements, plus amounts earned under enhanced benefit arrangements. The expense associated with the enhanced benefits was recognized ratably over the estimated service period required for the employee to earn the benefit upon termination. In 2015, we recorded other exit related costs of $15 million (2014: $65 million). In 2016, we paid $2 million (2015: $21 million; 2014: $158 million) for accrued facility and other exit costs. The facility and other exit costs related to charges associated with the cessation of use of certain leased office space, contract terminations, and costs associated with the shutdown of Port Reading refining operations. 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

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 $1,468 million, substantially all of which relates to loss carryforwards in Norway. The deferred tax asset attributable to U.S. federal net operating losses, net of valuation allowances, is $39 million. A full valuation allowance is established against the deferred tax asset attributable to U.S. state net operating losses. At December 31, 2016, we have U.S. federal, U.S. state and foreign alternative minimum tax credit carryforwards of $77 million which can be carried forward indefinitely, and approximately $6 million of other business credit carryforwards. The deferred tax asset attributable to these credits, net of valuation allowances, is $1 million. A full valuation allowance is established against our foreign tax credit carryforwards of $81 million, which begin to expire in 2017.

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, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:

	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 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

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 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

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 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. The ROD does not address the upper nine miles of the Lower Passaic River, which may require additional remedial action. In addition, the federal trustees for natural resources have begun a separate assessment of damages to natural resources in the Passaic River. Given that the EPA has not selected a remedy for the entirety of the Lower Passaic River, total remedial costs cannot be reliably estimated at this time. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us because there are numerous other parties who we expect will share in the cost of remediation and damages and our former terminal did not store or use contaminants which are of the greatest concern in the river sediments and could not have contributed contamination along most of the river’s length.

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

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).

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

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Related Party Transactions

Related Party Transactions

12 Months Ended

Dec. 31, 2016

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 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, crude 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, crude 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 Statement of Consolidated Income. 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 Statement of Consolidated Income. 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 amounted to a gain of $56 million for the year-ended December 31, 2016 (2015: loss of $344 million; 2014: loss of $756 million). Cumulative currency translation adjustments reduced stockholders’ equity by $1,045 million at December 31, 2016 and $1,101 million at December 31, 2015.

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 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 January 1		Charged to Costs and Expenses			Charged to Other Accounts			Deductions from Reserves		Balance December 31
		(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 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, which requires debt issuance costs to be presented in the balance sheet as a direct reduction to the associated debt liability. The Consolidated Balance Sheet at December 31, 2015 has been recast to reduce Other assets and Long-term debt by $38 million. In 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements – Going Concern. This ASU requires that management evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued. This ASU is effective for us beginning in the fourth quarter of 2016. The adoption of ASU 2014-15 did not have an impact on our consolidated financial statements.
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 CO₂ for tertiary recovery are expensed as incurred. The costs of exploratory wells that find oil and gas reserves are capitalized pending determination of whether proved reserves have been found. Exploratory drilling costs remain capitalized after drilling is completed if (1) the well has found a sufficient quantity of reserves to justify completion as a producing well and (2) sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If either of those criteria is not met, or if there is substantial doubt about the economic or operational viability of a project, the capitalized well costs are charged to expense. Indicators of sufficient progress in assessing reserves and the economic and operating viability of a project include commitment of project personnel, active negotiations for sales contracts with customers, negotiations with governments, operators and contractors, firm plans for additional drilling and other factors. 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 or when events or circumstances indicate that the carrying amount of the goodwill may not be recoverable based on a two-step process. In step one of the impairment test, the fair value of a reporting unit is compared with its carrying amount, including goodwill. If the fair value of the reporting unit exceeds its carrying value, goodwill is not impaired. If the carrying value of the reporting unit exceeds its fair value, we perform step two to determine possible impairment by comparing the implied fair value of goodwill with the carrying amount. If the implied fair value of goodwill is less than its carrying amount, an impairment loss would be recorded. In addition to our annual test, we also performed separate goodwill impairment tests at December 31, 2015 and June 30, 2015. See 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. Our policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized currently in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges) or hedges of firm commitments (fair value hedges). The effective portion of changes in fair value of derivatives that are designated as cash flow hedges is recorded as a component of other comprehensive income (loss) while the ineffective portion of the changes in fair value is recorded currently in earnings. Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings. Changes in fair value of derivatives designated as fair value hedges are recognized currently in earnings. The change in fair value of the related hedged commitment is recorded as an adjustment to its carrying amount and recognized currently in earnings.
Fair Value Measurements	Fair Value Measurements: 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, as a new ASC Topic, ASC 842. The new standard will require assets and liabilities to be reported on the balance sheet for all leases with lease terms greater than one year, including leases currently treated as operating leases under the existing standard. This ASU is effective for us beginning in the first quarter of 2019, with early adoption permitted. We are currently assessing the impact of the ASU on our consolidated financial statements. In March 2016, the FASB issued Accounting Standards Update (ASU) 2016-09, Improvements to Employee Share-Based Payment Accounting. This ASU makes changes to various provisions associated with share-based accounting, including provisions affecting the accounting for income taxes, the accounting for forfeitures, and the consideration of net settlement provisions on the balance sheet classification of the share-based award. This ASU is effective for us beginning in the first quarter of 2017. The adoption of ASU 2016 – 09 is not expected to have a material impact on our consolidated financial statements. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared to the current "incurred loss" model. This ASU is effective for us beginning in the first quarter of 2020, with early adoption permitted from the first quarter of 2019. We are currently assessing the impact of the ASU on our consolidated financial statements. In October 2016, the FASB issued ASU 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory. This ASU will require the recognition of income tax consequences from intra-entity transfer of assets other than inventory when the transfer occurs. This ASU is effective for us beginning in the first quarter of 2018, with early adoption permitted. We plan to adopt ASU 2016-16 in the first quarter of 2017, which is not expected to have a material impact on our consolidated financial statements. In January 2017, the FASB issued ASU 2017-01, Business Combinations – Clarifying the Definition of a Business. This ASU provides a screen that excludes an integrated set of activities and assets from the definition of a business if the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or group of similar identifiable assets. This ASU also clarifies that an integrated set of activities and assets must include (at a minimum), an input and a substantive process that together significantly contribute to the ability to create output to be considered a business. This ASU is effective for us beginning in the first quarter of 2018, with early application permitted. We are currently assessing the impact of the ASU on our consolidated financial statements. In January 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment. This ASU modifies the concept of goodwill impairment from a condition that exists when the carrying amount of goodwill exceeds its implied fair value to the condition that exists when the carrying amount of the reporting unit exceeds its fair value. Thus, an entity should recognize an impairment charge for the amount by which the carrying amount of a reporting unit exceeds its fair value. The impairment charge would be limited by the amount of goodwill allocated to the reporting unit. This ASU removes the requirement to determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if the reporting unit had been acquired in a business combination. This ASU is effective for us beginning in the first quarter of 2020, with early adoption permitted. We are currently assessing the impact of the ASU on our consolidated financial statements.

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 (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

	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)

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)

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

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

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Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2016

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)

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 aggregate total debt maturing during the next five years is as follows (in millions): 2017: $112; 2018: $123; 2019: $448; 2020: $598 and 2021: $-.

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 (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)Includes benefit related to discontinued operations of $4 million for 2014.

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)

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

	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)

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, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:

	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 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)

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 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)

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 and Commitments (Tables)

12 Months Ended

Dec. 31, 2016

Commitments And Contingencies Disclosure [Abstract]

Schedule of Unconditional Purchase Obligations and Commitments

			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)

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 (Tables)

12 Months Ended

Dec. 31, 2016

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 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 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

Amount of cumulative effect of the change in accounting principle or new accounting pronouncement on retained earnings or other components of equity or net assets in the statement of financial position as of the beginning of the earliest period presented.

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		$ 1.00
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 (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 - Components of Property, Plant and Equipment (Detail) - USD ($)
$ in Millions

Dec. 31, 2016

Dec. 31, 2015

Less: Reserves for depreciation, depletion, amortization and lease impairment

$ 46,907

$ 46,826

23,312

20,474

Property, Plant and Equipment — Net

^[1]

23,595

26,352

Exploration and Production

Wells, equipment and related facilities

Unproved properties

710

958

Proved properties

4,258

4,202

38,821

38,738

43,789

43,898

Bakken Midstream

3,018

2,757

Corporate and Other

$ 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 Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) Well	Dec. 31, 2015 USD ($) Well	Dec. 31, 2014 USD ($) 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 Equipment - Capitalized Exploratory Well Costs - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) km² Well	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
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 Equipment - Exploratory Drilling Costs Capitalized (Detail) $ in Millions	Dec. 31, 2016 USD ($)
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 2015
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 2014
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 2013
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 2012
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 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 Information (Detail) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
Goodwill - Additional Information (Detail) $ in Millions	Jun. 30, 2015 USD ($) Segment	Jun. 30, 2015 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
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 Information (Detail) - USD ($)		12 Months Ended
Impairment - Additional Information (Detail) - USD ($)	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 - Additional Information (Detail) - USD ($)
$ in Millions

12 Months Ended

36 Months Ended

Jul. 02, 2015

Jul. 01, 2015

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2016

Dec. 31, 2013

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%

Cash and cash equivalents

$ 2,732

2,716

$ 2,444

$ 2,732

$ 1,814

^[1]

23,595

26,352

23,595

Bakken Midstream

Term Loan A facility - Face amount

$ 600

600

Term Loan A facility - Term

5 years

HIP

Cash and cash equivalents

$ 2

$ 3

Bakken Midstream liabilities non-recourse to Hess Corporation

$ 2,528

2,358

$ 2,528

liabilities totaling $841 million (2015: $831 million)

Capital in Excess of Par

After tax gain from sale of equity interest

763

Noncontrolling Interests

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 Information (Detail)	12 Months Ended
Dispositions - Additional Information (Detail)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($) a	Dec. 31, 2014 USD ($) 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 - 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

Amount before tax of income (loss) from a discontinued operation. Includes, but is not limited to, the income (loss) from operations during the phase-out period, gain (loss) on disposal, gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and adjustments to a prior period gain (loss) on disposal.

Amount of tax expense (benefit) related to a discontinued operation. Includes, but is not limited to, tax expense (benefit) related to income (loss) from operations during the phase-out period, tax expense (benefit) related to gain (loss) on disposal, tax expense (benefit) related to gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and tax expense (benefit) related to adjustments of a prior period gain (loss) on disposal.

Amount after tax of income (loss) from a discontinued operation including the portion attributable to the noncontrolling interest. Includes, but is not limited to, the income (loss) from operations during the phase-out period, gain (loss) on disposal, gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and adjustments to a prior period gain (loss) on disposal.

Amount after tax of income (loss) from a discontinued operation attributable to the noncontrolling interest. Includes, but is not limited to, the income (loss) from operations during the phase-out period, gain (loss) on disposal, gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and adjustments to a prior period gain (loss) on disposal.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5B
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721673-107760

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=65878427&loc=d3e1012-107759

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=65878427&loc=SL51721523-107759

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=68079674&loc=SL4569616-111683

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=68079674&loc=SL4568447-111683

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 3B
-URI http://asc.fasb.org/extlink&oid=65878427&loc=SL51721525-107759

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5C
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=64827811&loc=SL51721675-107760

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
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-Paragraph 1
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=65878427&loc=d3e957-107759

Amount after tax of income (loss) from a discontinued operation attributable to the parent. Includes, but is not limited to, the income (loss) from operations during the phase-out period, gain (loss) on disposal, gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and adjustments to a prior period gain (loss) on disposal.

Discontinued Operations - Additional Information (Detail) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2014 USD ($)	Dec. 31, 2014 USD ($) 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 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 - 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 - 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	2047

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

Debt - Additional Information (Detail) - USD ($)			1 Months Ended		12 Months Ended
Debt - Additional Information (Detail) - USD ($)	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				2019	2019
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			2029		2029
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			2031		2031
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			2017		2017

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 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	2018

Share-based Compensation - Additional Information (Detail) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) $ / shares shares
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Number of authorized common stock shares under LTIP, as amended \| shares	38.0
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 - 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 - Share-based Compensation Expense (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2014 USD ($)
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 - 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	55.00
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 - 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	$ 21.00	$ 26.46

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 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 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 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 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 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 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 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	2038	2038	2029

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 Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan (Detail) $ in Millions	Dec. 31, 2016 USD ($)
Compensation And Retirement Disclosure [Abstract]
2017	$ 138
2018	123
2019	133
2020	135
2021	136
Years 2022 to 2026	$ 725

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	2017
Accrued liabilities of exit costs to be settled in next several years	$ 14

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 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) 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 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 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	2024
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	2021
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	2017
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	2017
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 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 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 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 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 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	0.00	(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	0.0	1.5
Stock Options
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0.0	0.0	1.8
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0.0	0.0	0.7
Mandatory Convertible Preferred Stock
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Effect of dilutive securities	0.0	0.0	0.0

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	0.0
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	0.0
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	0.0

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	$ 1.00	$ 1.00	$ 1.00

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 - 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 Information (Detail) - USD ($) $ in Millions		12 Months Ended
	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 Rental Payments (Detail) $ in Millions	Dec. 31, 2016 USD ($)
Leases [Abstract]
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

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 and Commitments - Additional Information (Detail) - USD ($)			1 Months Ended
	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 and Commitments - Schedule of Unconditional Purchase Obligations and Commitments (Detail) $ in Millions	Dec. 31, 2016 USD ($)
Capital Expenditures
Loss Contingencies [Line Items]
Total	$ 708
2017	632
2018 and 2019	76
2020 and 2021	0
Thereafter	0
Operating Expenses
Loss Contingencies [Line Items]
Total	497
2017	393
2018 and 2019	76
2020 and 2021	18
Thereafter	10
Transportation and Related Contracts
Loss Contingencies [Line Items]
Total	1,560
2017	182
2018 and 2019	457
2020 and 2021	433
Thereafter	$ 488

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

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 - Financial Information by Major Geographic Area (Detail) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Net income (loss) from continuing operations attributable to Hess Corporation

$ 4,762

$ 6,636

$ 10,737

(6,132)

(3,008)

1,692

3,244

3,955

3,224

1,616

2,222

(1,299)

744

28,621

34,157

^[1]

23,595

26,352

Corporate, Interest and Other

1,921

4,049

5,274

Net income (loss) from continuing operations attributable to Hess Corporation

(1,210)

(377)

(404)

609

(240)

(252)

2,600

2,540

^[1]

121

United States

Net income (loss) from continuing operations attributable to Hess Corporation

3,085

4,150

6,270

(2,353)

(1,834)

654

2,133

2,449

1,751

986

411

(522)

446

16,096

18,365

^[1]

14,596

15,729

1,400

2,727

3,467

Europe

Net income (loss) from continuing operations attributable to Hess Corporation

610

870

1,557

(439)

(408)

226

502

635

683

279

243

(84)

5,180

6,207

^[1]

4,907

5,300

297

524

Africa

Net income (loss) from continuing operations attributable to Hess Corporation

601

945

2,002

(355)

(274)

545

375

539

487

100

244

(48)

435

1,507

2,178

^[1]

1,266

1,682

160

399

Asia and Other Countries

Net income (loss) from continuing operations attributable to Hess Corporation

466

671

908

(1,775)

(115)

671

224

317

289

251

715

(405)

3,238

4,867

^[1]

2,779

3,520

$ 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 - Financial Information by Major Geographic Area (Parenthetical) (Detail) - USD ($)
$ in Millions

Dec. 31, 2016

Dec. 31, 2015

^[1]

$ 23,595

$ 26,352

Norway