View Filing Data

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

32,504

46,907

16,312

23,312

Property, plant and equipment — net

16,192

23,595

^[1]

Goodwill

360

375

Deferred income taxes

Other assets

382

316

Total Assets

23,112

28,621

Current Liabilities:

Accounts payable

435

433

Accrued liabilities

1,337

1,609

Taxes payable

Current maturities of long-term debt

580

112

Total current liabilities

2,435

2,251

Long-term debt

6,397

6,694

Deferred income taxes

429

1,144

Asset retirement obligations

753

1,912

Other liabilities and deferred credits

744

1,029

Total Liabilities

10,758

13,030

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 (2016: 575,000)

Common stock, par value $1.00; Authorized — 600,000,000 shares Issued — 315,053,615 shares (2016: 316,523,200)

315

317

Capital in excess of par value

5,824

5,773

Retained earnings

5,597

10,147

Accumulated other comprehensive income (loss)

(686)

(1,704)

Total Hess Corporation stockholders’ equity

11,051

14,534

Noncontrolling interests

1,303

1,057

Total equity

12,354

15,591

Total Liabilities and Equity

$ 23,112

$ 28,621

[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

Consolidated Balance Sheet (Parenthetical) - $ / shares	12 Months Ended
Consolidated Balance Sheet (Parenthetical) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1.00	$ 1.00
Preferred stock, shares authorized	20,000,000	20,000,000
Preferred stock, shares issued	575,000	575,000
Preferred stock, liquidation preference per share	$ 1,000	$ 1,000
Cumulative mandatory convertible series	8.00%	8.00%
Common stock, par value	$ 1.00	$ 1.00
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	315,053,615	316,523,200

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues and Non-Operating Income
Sales and other operating revenues	$ 5,466	$ 4,762	$ 6,636
Gains (losses) on asset sales, net	(86)	23	51
Other, net	25	59	(126)
Total revenues and non-operating income	5,405	4,844	6,561
Costs and Expenses
Marketing, including purchased oil and gas	1,267	1,063	1,294
Operating costs and expenses	1,445	1,880	2,029
Production and severance taxes	119	101	146
Exploration expenses, including dry holes and lease impairment	507	1,442	881
General and administrative expenses	434	415	557
Interest expense	325	338	341
Loss on debt extinguishment	0	148	0
Depreciation, depletion and amortization	2,883	3,244	3,955
Impairment	4,203	67	1,616
Total costs and expenses	11,183	8,698	10,819
Income (Loss) from Continuing Operations Before Income Taxes	(5,778)	(3,854)	(4,258)
Provision (benefit) for income taxes	(1,837)	2,222	(1,299)
Income (Loss) from Continuing Operations	(3,941)	(6,076)	(2,959)
Income (Loss) from Discontinued Operations, Net of Income Taxes	0	0	(48)
Net Income (Loss)	(3,941)	(6,076)	(3,007)
Less: Net income (loss) attributable to noncontrolling interests	133	56	49
Net Income (Loss) Attributable to Hess Corporation	(4,074)	(6,132)	(3,056)
Less: Preferred stock dividends	46	41	0
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (4,120)	$ (6,173)	$ (3,056)
Net Income (Loss) Per Common Share - Basic:
Continuing operations	$ (13.12)	$ (19.92)	$ (10.61)
Discontinued operations	0	0	(0.17)
Net Income (Loss) Per Common Share	(13.12)	(19.92)	(10.78)
Net Income (Loss) Per Common Share - Diluted:
Continuing operations	(13.12)	(19.92)	(10.61)
Discontinued operations	0	0	(0.17)
Net Income (Loss) Per Common Share	$ (13.12)	$ (19.92)	$ (10.78)
Weighted Average Number of Common Shares Outstanding (Diluted)	314.1	309.9	283.6
Common Stock Dividends Per Share	$ 1.00	$ 1.00	$ 1.00

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ (3,941)	$ (6,076)	$ (3,007)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	18	0	(118)
Income taxes on effect of hedge (gains) losses reclassified to income	0	0	44
Net effect of hedge (gains) losses reclassified to income	18	0	(74)
Change in fair value of cash flow hedges	(156)	0	121
Income taxes on change in fair value of cash flow hedges	0	0	(45)
Net change in fair value of cash flow hedges	(156)	0	76
Change in derivatives designated as cash flow hedges, after taxes	(138)	0	2
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	35	(155)	17
Income taxes on actuarial changes in plan liabilities	0	20	4
(Increase) reduction in unrecognized actuarial losses, net	35	(135)	21
Amortization of net actuarial losses	77	60	92
Income taxes on amortization of net actuarial losses	0	(21)	(31)
Net effect of amortization of net actuarial losses	77	39	61
Recognition of accumulated actuarial losses - HOVENSA	0	0	15
Income taxes on recognition of accumulated actuarial losses - HOVENSA	0	0	(9)
Recognition of accumulated actuarial losses, net of taxes - HOVENSA	0	0	6
Change in pension and other postretirement plans, after taxes	112	(96)	88
Foreign currency translation adjustment
Foreign currency translation adjustment	144	56	(344)
Asset disposition	900	0	0
Change in foreign currency translation adjustment	1,044	56	(344)
Other Comprehensive Income (Loss)	1,018	(40)	(254)
Comprehensive Income (Loss)	(2,923)	(6,116)	(3,261)
Less: Comprehensive income (loss) attributable to noncontrolling interests	133	56	49
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (3,056)	$ (6,172)	$ (3,310)

Statement of Consolidated Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows From Operating Activities
Net income (loss)	$ (3,941)	$ (6,076)	$ (3,007)
Adjustments to reconcile to net cash provided by (used in) operating activities
(Gains) losses on asset sales, net	86	(23)	(51)
Depreciation, depletion and amortization	2,883	3,244	3,955
Impairment	4,203	67	1,616
Loss from equity affiliates	0	0	25
Exploratory dry hole costs	268	1,064	410
Exploration lease and other impairment	44	145	182
Stock compensation expense	86	73	97
Non-cash (gains) losses on commodity derivatives, net	97	0	48
Provision (benefit) for deferred income taxes and other tax accruals	(2,001)	2,200	(1,319)
Loss on debt extinguishment	0	148	0
(Income) loss from discontinued operations, net of income taxes	0	0	48
Changes in operating assets and liabilities
(Increase) decrease in accounts receivable	(340)	96	793
(Increase) decrease in inventories	(64)	77	29
Increase (decrease) in accounts payable and accrued liabilities	(44)	(87)	(424)
Increase (decrease) in taxes payable	(34)	9	(222)
Changes in other operating assets and liabilities	(298)	(142)	(164)
Net cash provided by (used in) operating activities - continuing operations	945	795	2,016
Net cash provided by (used in) operating activities - discontinued operations	0	0	(35)
Net cash provided by (used in) operating activities	945	795	1,981
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(1,788)	(1,974)	(3,952)
Additions to property, plant and equipment - Midstream	(149)	(277)	(369)
Proceeds from asset sales	3,296	140	50
Other, net	(1)	21	(44)
Net cash provided by (used in) investing activities - continuing operations	1,358	(2,090)	(4,315)
Net cash provided by (used in) investing activities - discontinued operations	0	0	109
Net cash provided by (used in) investing activities	1,358	(2,090)	(4,206)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	(153)	43	110
Debt with maturities of greater than 90 days – Borrowings	800	1,496	600
Debt with maturities of greater than 90 days – Repayments	(459)	(1,455)	(67)
Proceeds from issuance of Hess Midstream Partnership LP units	366	0	0
Proceeds from issuance of preferred stock	0	557	0
Proceeds from issuance of common stock	0	1,087	0
Common stock acquired and retired	(110)	0	(142)
Cash dividends paid	(363)	(350)	(287)
Noncontrolling interests, net	(243)	(23)	2,296
Other, net	(26)	(44)	(13)
Net cash provided by (used in) financing activities - continuing operations	(188)	1,311	2,497
Net cash provided by (used in) financing activities - discontinued operations	0	0	0
Net cash provided by (used in) financing activities	(188)	1,311	2,497
Net Increase (Decrease) in Cash and Cash Equivalents	2,115	16	272
Cash and Cash Equivalents at Beginning of Year	2,732	2,716	2,444
Cash and Cash Equivalents at End of Year	$ 4,847	$ 2,732	$ 2,716

Statement of Consolidated Equity - USD ($) $ in Millions	Total	Mandatory Convertible Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Total Hess Stockholders' Equity	Noncontrolling Interests
Balance at Dec. 31, 2014	$ 22,320		$ 286	$ 3,277	$ 20,052	$ (1,410)	$ 22,205	$ 115
Net income (loss)	(3,007)				(3,056)		(3,056)	49
Other comprehensive income (loss)	(254)					(254)	(254)
Share-based compensation, including income taxes	106		1	105			106
Dividends on common stock	(287)				(287)		(287)
Common stock acquired and retired	(91)		(1)	(18)	(72)		(91)
Formation of Midstream joint venture	2,061			763			763	1,298
Noncontrolling interests, net	(447)							(447)
Balance at Dec. 31, 2015	20,401		286	4,127	16,637	(1,664)	19,386	1,015
Net income (loss)	(6,076)				(6,132)		(6,132)	56
Other comprehensive income (loss)	(40)					(40)	(40)
Stock issuance	1,607	$ 1	29	1,577			1,607
Share-based compensation, including income taxes	71		2	69			71
Dividends on preferred stock	(41)				(41)		(41)
Dividends on common stock	(317)				(317)		(317)
Common stock acquired and retired	0
Noncontrolling interests, net	(14)							(14)
Balance at Dec. 31, 2016	15,591	1	317	5,773	10,147	(1,704)	14,534	1,057
Cumulative effect of adoption of new accounting standards at Dec. 31, 2016	(37)			2	(39)		(37)
Net income (loss)	(3,941)				(4,074)		(4,074)	133
Other comprehensive income (loss)	1,018					1,018	1,018
Share-based compensation, including income taxes	93		1	92			93
Dividends on preferred stock	(46)				(46)		(46)
Dividends on common stock	(317)				(317)		(317)
Common stock acquired and retired	(120)		(3)	(43)	(74)		(120)
Hess Midstream Partners LP units issuance	356							356
Noncontrolling interests, net	(243)							(243)
Balance at Dec. 31, 2017	$ 12,354	$ 1	$ 315	$ 5,824	$ 5,597	$ (686)	$ 11,051	$ 1,303

Nature of Operations, Basis of Presentation and Summary of Accounting Policies	12 Months Ended
	Dec. 31, 2017
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, incorporated in the State of Delaware in 1920, 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, the Malaysia/Thailand Joint Development Area (JDA) and Malaysia. The Corporation conducts exploration activities primarily offshore Guyana, Suriname, Canada and in the Gulf of Mexico, including at the Stabroek Block, offshore Guyana, where we have participated in six significant crude oil discoveries and sanctioned the first phase of a multi-phase development project at the Liza Field. The Corporation’s Midstream operating segment provides fee-based services, including gathering, compressing and processing natural gas and fractionating natural gas liquids (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. On January 1, 2017, the Corporation’s interests in a Permian Basin gas plant in West Texas and related CO₂ assets, and water handling assets in North Dakota were transferred from the E&P segment to the Midstream segment as a result of organizational changes to the management of those assets. These assets were wholly-owned by the Corporation and were not included in our HIP joint venture. Prior period information has been recast to conform to the current period presentation. See Note 22, Segment Information. In the third quarter of 2017, we completed the sale of our assets in the Permian Basin. 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. See Note 7, Hess Infrastructure Partners LP. Our undivided interests in unincorporated oil and gas E&P 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 2017, we adopted Accounting Standards Update (ASU) 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory. This ASU requires the recognition of income tax consequences from intra-entity transfer of assets other than inventory when the transfer occurs. The adoption of this standard was applied on a modified retrospective basis through a cumulative effect adjustment as of January 1, 2017, that resulted in a decrease to Retained earnings and a decrease to Deferred income taxes, included in non-current assets, of $37 million. In 2017, we adopted 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, the presentation of the statements of cash flow, and the consideration of net settlement provisions on the balance sheet classification of the share-based award. As part of the adoption of this ASU, we elected to account for forfeitures of share-based awards in the period when they occur. The effect of this election was applied on a modified retrospective basis through a cumulative effect adjustment as of January 1, 2017, that resulted in a decrease to Retained earnings and an increase to Capital in excess of par value of $2 million. The cumulative effect adjustment to deferred tax assets for excess tax benefits not previously recognized as of the beginning of the period was offset by a corresponding change in valuation allowance, resulting in no cumulative effect adjustment to Retained earnings. Further, as part of the adoption of this ASU, we have applied its provisions affecting excess tax benefits on a prospective basis in the statement of income and the statement of cash flows, effective January 1, 2017. 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 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. 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 impairment 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 3, 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. 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 are no longer indefinitely reinvested with respect to the book in excess of tax basis in the investment in our foreign subsidiaries. Because of U.S. tax reform we expect that the future reversal of such temporary differences will occur free of material taxation. We classify interest and penalties associated with uncertain tax positions as income tax expense. We account for the U.S. tax effect of global intangible low-taxed income earned by foreign subsidiaries in the period that such income is earned. Asset Retirement Obligations: We have material legal obligations to remove and dismantle long‑lived assets and to restore land or the seabed at certain E&P 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 over the service period for the entire award, whether the award was granted with ratable or cliff vesting, net of actual forfeitures. 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 our 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 our former operations in Norway that did not use the U.S. Dollar as the functional currency, adjustments resulting from translating foreign currency assets and liabilities into U.S. Dollars were recorded in the Consolidated Balance Sheet in a separate component of equity titled Accumulated other comprehensive income (loss) prior to the disposition. See Note 2, Dispositions. 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 2017, 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. Our analysis of contracts with customers against the requirements of ASC 606 is complete and we have not identified any changes to the timing of revenue recognition based on requirements of the standard that would have a material impact on our consolidated financial statements. We will 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, if any, 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 Consolidated 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 have developed and are executing a project plan for the implementation of ASC 842 in the first quarter of 2019. We are progressing our assessment of existing leases and evaluating our disclosure processes with reference to the requirements of the standard. We continue to assess the impact of the ASU 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 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. Application of this ASU is on a prospective basis only when adopted. 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. In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits. This ASU requires that an employer disaggregate the service cost component from the other components of net periodic benefit cost. The amendments also provide explicit guidance on how to present the service cost component and the other components of net periodic benefit cost in the statement of income and allow only the service cost component of net periodic benefit cost to be eligible for capitalization. This ASU is effective for us beginning in the first quarter of 2018. We are currently assessing the impact of the ASU on our consolidated financial statements. In August 2017, FASB issued ASU 2017-12, Derivatives and Hedging – Targeted Improvements to Accounting for Hedging Activities. This ASU aims to improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. In addition, this ASU make certain targeted improvements to simplify the application of the existing hedge accounting guidance. This ASU is effective for us beginning in the first quarter of 2019, with early application permitted. We plan to adopt this ASU in the first quarter of 2018 and expect the impact of adoption to our consolidated financial statements to be immaterial.

Disposition

12 Months Ended

Dec. 31, 2017

Disposition Of Businesses [Abstract]

Dispositions

2. Dispositions

2017: We completed the sale of our enhanced oil recovery assets in the Permian Basin in August for proceeds of $597 million, after normal closing adjustments, and recognized a pre-tax gain of $273 million ($280 million attributable to Hess Corporation after income taxes and noncontrolling interest). This sale transaction included both upstream and midstream assets resulting in an after-tax gain of $314 million allocated to the E&P segment, and an after-tax loss of $34 million allocated to the Midstream segment. In November, we completed the sale of our interests in Equatorial Guinea for proceeds of $449 million, after normal closing adjustments, which resulted in a pre-tax gain of $486 million ($486 million after income taxes). In December, we completed the sale of our interests in the Valhall and Hod assets, offshore Norway for proceeds of $2,056 million, after normal closing adjustments, which resulted in a pre-tax loss of $857 million ($857 million after income taxes). This loss includes a recognition in earnings of $900 million for cumulative translation adjustments that were previously reflected within Accumulated Other Comprehensive Income (Loss) in Stockholders’ Equity. We also sold certain U.S. onshore assets for proceeds totaling approximately $194 million and recognized net pre-tax gains totaling $12 million ($12 million after income taxes). The 2017 asset sales of higher cost, mature assets will provide funds toward our future development projects in the Stabroek Block, offshore Guyana, where we, and our partners, have discovered significant crude oil and natural gas resources.

Pre-tax income (loss) associated with our interests in Equatorial Guinea and Norway, excluding the financial statement impacts resulting from the asset sales in 2017, were as follows for the three years ended December 31:

	2017			2016			2015
	(In millions)
Equatorial Guinea (a)	$	69		$	(95	)	$	(23	)
Norway (b)		(55	)		(195	)		(276	)
Income (Loss) from Continuing Operations Before Income Taxes	$	14		$	(290	)	$	(299	)

(a)	Pre-tax income for 2017 excludes the gain of $486 million related to sale of our assets in November 2017.

(b)	Pre-tax loss for 2017 excludes the loss of $857 million related to sale of our assets in December 2017. In addition, the 2017 loss excludes a pre-tax impairment charge of $2,503 million associated with the disposition.

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).

Impairment	12 Months Ended
Impairment	Dec. 31, 2017
Asset Impairment Charges [Abstract]
Impairment	3. Impairment 2017: In the third quarter, we recognized a pre-tax charge of $2,503 million ($550 million after income taxes) to impair the carrying value of our interests in Norway based on an anticipated sale of the asset, which closed in the fourth quarter of 2017. See Note 2, Dispositions. In the fourth quarter, we recognized pre-tax impairment charges to reduce the carrying value of our interests in the Stampede Field by $1,095 million ($1,095 million after income taxes), and the Tubular Bells Field by $605 million ($605 million after income taxes) primarily as a result of a lower long-term crude oil price outlook. The Stampede Field had significant capitalized exploration and appraisal costs that were incurred on a 100% working interest basis on the Pony discovery prior to unitizing into the Stampede project. The fourth quarter impairment charges were based on a total fair value estimate of approximately $1.1 billion that was determined using internal projected discounted cash flows. 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. 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 approximated fair value. 2015: We recorded pre-tax goodwill impairment charges totaling $1,483 million ($1,483 million after income taxes) in our E&P segment using multiple valuation methodologies. For purposes of assessing the fair value of goodwill, we considered internal projected discounted cash flows of producing assets and known development projects, as well as the relative market valuation of similar peer companies using market multiples, and other observable market data. Goodwill was written down to its implied fair value of zero. 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 internal projected discounted cash flows. Each of the valuation methods used in the determination of the impairment charges above represent Level 3 fair value measurements.

Inventories

12 Months Ended

Dec. 31, 2017

Inventory Disclosure [Abstract]

Inventories

4. Inventories

Inventories at December 31 were as follows:

	2017		2016
	(In millions)
Crude oil and natural gas liquids	$	59	$	77
Materials and supplies		173		246
Total Inventories	$	232	$	323

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2017

Property Plant And Equipment [Abstract]

Property, Plant and Equipment

5. Property, Plant and Equipment

Property, plant and equipment at December 31 were as follows:

	2017		2016
	(In millions)
Exploration and Production
Unproved properties	$	520	$	710
Proved properties		3,162		4,249
Wells, equipment and related facilities		25,550		38,250
		29,232		43,209
Midstream		3,219		3,598
Corporate and Other		53		100
Total — at cost		32,504		46,907
Less: Reserves for depreciation, depletion, amortization and lease impairment		16,312		23,312
Property, Plant and Equipment — Net	$	16,192	$	23,595

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:

	2017			2016			2015
	(In millions)
Balance at January 1	$	597		$	1,415		$	1,416
Additions to capitalized exploratory well costs pending the determination of proved reserves		116			79			424
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(165	)		—			(72	)
Capitalized exploratory well costs charged to expense		(268	)		(897	)		(356	)
Dispositions and other		24			—			3
Balance at December 31	$	304		$	597		$	1,415
Number of Wells at December 31		12			17			35

Additions to capitalized exploratory well costs primarily related to drilling activity at the Stabroek license offshore Guyana in 2017, 2016 and 2015, and the Gulf of Mexico in 2016 and 2015. Reclassifications to wells, facilities and equipment based on the determination of proved reserves primarily related to the sanction of the first phase of Liza Field development, offshore Guyana in 2017 and Equatorial Guinea in 2015.

Capitalized exploratory well costs charged to expense include the following:

2017: In Ghana, at the Hess operated offshore Deepwater Tano/Cape Three Points license (Hess 50% license interest), management determined in the fourth quarter of 2017 that it would not develop the previously discovered fields. As a result, we recorded a charge of $268 million to write-off previously capitalized exploration wells. See Note 24, Subsequent Events.

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. These properties were sold in 2017. In the second quarter of 2016, 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 low commodity 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. We also expensed three wells with discovered resources offshore Australia that we determined would not be included in the development concept for the Equus project.

The preceding table excludes exploratory dry hole costs of $167 million in 2016 and $54 million in 2015, which were incurred and subsequently expensed in the same year.

Exploratory well costs capitalized for greater than one year following completion of drilling were $170 million at December 31, 2017, separated by year of completion as follows (in millions):

2016	$	—
2015		166
2014		—
2013		4
	$	170

Gulf of Mexico: Approximately 70% of the capitalized well costs in excess of one year relates to the appraisal of 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 conducting appraisal activities on adjacent acreage and is evaluating plans for development of the northern portion of the Shenzi Field.

JDA: Approximately 20% of the capitalized well costs in excess of one year relates to the JDA in the Gulf of Thailand (Hess 50%) where hydrocarbons were encountered in three successful exploration wells drilled in the western part of Block A-18. The operator is currently conducting subsurface evaluations and pre-development planning to facilitate commercial negotiations with the regulator for an extension of the existing gas sales contract to include development of the western part of the block area.

Goodwill

12 Months Ended

Dec. 31, 2017

Goodwill And Intangible Assets Disclosure [Abstract]

Goodwill

6. Goodwill

The changes in the carrying amount of goodwill were as follows:

	Exploration and Production		Midstream			Total
	(In millions)
Balance at December 31, 2016	$	—	$	375		$	375
Dispositions		—		(15	)		(15	)
Balance at December 31, 2017	$	—	$	360		$	360

The change in the carrying amount of goodwill relates to the sale of our enhanced oil recovery assets in the Permian Basin, including a gas plant and associated CO₂ assets. See Note 2, Dispositions.

Hess Infrastructure Partners LP	12 Months Ended
Hess Infrastructure Partners LP	Dec. 31, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Hess Infrastructure Partners LP	7. Hess Infrastructure Partners LP On July 1, 2015, we sold a 50% interest in Hess Infrastructure Partners LP (HIP) to Global Infrastructure Partners (GIP) for net cash consideration of approximately $2.6 billion. HIP and its affiliates primarily comprise our 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 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 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 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 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 Midstream segment. We consolidate the activities of HIP, a 50/50 joint venture between Hess Corporation and GIP, which qualifies as a variable interest entity (VIE) under U.S. GAAP. 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 capital in excess of par value 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. At December 31, 2017, HIP liabilities totaling $1,065 million (2016: $841 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 $356 million (2016: $2 million) and Property, plant and equipment, net totaling $2,520 million (2016: $2,528 million).

Hess Midstream Partners LP - Initial Public Offering	12 Months Ended
Hess Midstream Partners LP - Initial Public Offering	Dec. 31, 2017
Partners Capital Notes [Abstract]
Hess Midstream Partners LP - Initial Public Offering	8. Hess Midstream Partners LP – Initial Public Offering In April 2017, Hess Midstream Partners LP (the “Partnership”), sold 16,997,000 common units representing limited partner interests at a price of $23 per unit in an initial public offering (IPO) for net proceeds of $365.5 million, of which $350 million was distributed 50/50 to Hess Corporation and GIP. The Partnership owns an approximate 20% controlling interest in the operating companies that comprise our midstream joint venture, while HIP, the 50/50 joint venture between Hess Corporation and GIP, owns the remaining 80%. Hess Corporation and GIP each own a direct 33.75% limited partner interest in the Partnership and a 50% indirect ownership interest through HIP in the Partnership’s general partner, which has a 2% economic interest in the Partnership plus incentive distribution rights. The public unit holders own a 30.5% limited partner interest in the Partnership.

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2017

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

9. Asset Retirement Obligations

The following table describes changes to our asset retirement obligations:

	2017			2016
	(In millions)
Balance at January 1	$	2,128		$	2,383
Liabilities incurred		62			42
Liabilities settled or disposed of		(1,464	)		(196	)
Accretion expense		97			117
Revisions of estimated liabilities		(54	)		(230	)
Foreign currency translation		32			12
Balance at December 31		801			2,128
Less: Current Obligations		48			216
Long-term Obligations at end of period	$	753		$	1,912

The liabilities settled or disposed of primarily relate to the sale of our interests in Norway and Equatorial Guinea in 2017. The fair value of sinking fund deposits that are legally restricted for purposes of settling asset retirement obligations, which are reported in non-current Other assets in the Consolidated Balance Sheet, was $118 million at December 31, 2017 (2016: $102 million).

Debt

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Debt

10. Debt

Long‑term debt at December 31 consisted of the following:

	2017		2016
	(In millions)
Debt - Hess Corporation:
Fixed-rate public notes:
8.1% due 2019	$	349	$	349
3.5% due 2024		297		297
4.3% due 2027		991		989
7.9% due 2029		500		499
7.3% due 2031		679		679
7.1% due 2033		596		596
6.0% due 2040		740		740
5.6% due 2041		1,234		1,232
5.8% due 2047		493		493
Total fixed-rate public notes		5,879		5,874
Financing obligations associated with floating production system		118		192
Fair value adjustments - interest rate hedging		—		7
Total Debt - Hess Corporation	$	5,997	$	6,073

Debt - Midstream
Fixed-rate notes: 5.6% due 2026 - HIP	$	785	$	—
Term loan A facility - HIP		195		580
Revolving credit facility - HIP		—		153
Revolving credit facility - HESM		—		—
Total Debt - Midstream	$	980	$	733

Total Long-Term Debt:
Total debt (a)	$	6,977	$	6,806
Less: Current maturities of long-term debt		580		112
Total Long-Term Debt	$	6,397	$	6,694

(a)	At December 31, 2017 the fair value of total debt amounted to $7,718 million (2016: $7,548 million).

At December 31, 2017, the maturity profile of total debt was as follows:

	Total		Hess Corporation		Midstream
	(In millions)

2018	$	580	$	578	$	2
2019		51		40		11
2020		15		—		15
2021		16		—		16
2022		151		—		151
Thereafter		6,164		5,379		785
Total debt (excluding interest)	$	6,977	$	5,997	$	980

Debt – Hess Corporation:

Fixed-rate public notes:

At December 31, 2017, Hess Corporation’s fixed-rate public notes had a gross principal amount of $5,938 million (2016: $5,938 million) and a weighted average interest rate of 6.0% (2016: 6.0%). 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 $3,352 million of secured debt at December 31, 2017. Capitalized interest was $86 million in 2017 (2016: $61 million; 2015: $45 million).

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.

In February 2018, we purchased $350 million principal amount of 8.125% notes due 2019. See Note 24, Subsequent Events.

Credit facility:

In December 2017, the Corporation amended its $4 billion senior syndicated revolving credit facility by extending the facility for one year to January 2021, with a $3.7 billion commitment during the extension period. Borrowings on the facility will generally bear interest at 1.30% 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 60% of the Corporation’s total capitalization, defined as total debt plus stockholders’ equity. At December 31, 2017, 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.

Other outstanding letters of credit at December 31 were as follows:

	2017		2016
	(In millions)
Committed lines (a)	$	29	$	1
Uncommitted lines (a)		217		187
Total (b)	$	246	$	188

(a)	At December 31, 2017, committed and uncommitted lines have expiration dates through 2018.

(b)	At December 31, 2017, total outstanding letters of credit includes $215 million related to liabilities recorded in the Consolidated Balance Sheet (2016: $161 million).

Debt - Midstream:

Our Midstream segment holds the following non-recourse debt:

Hess Infrastructure Partners (HIP):

In November 2017, HIP issued $800 million of 5.625% senior notes, due in February 2026 and concurrently amended its senior unsecured credit facilities. HIP used a portion of the proceeds from the note issuance to repay borrowings under HIP’s credit facilities and to fund a distribution to the partners. The remaining proceeds will be used for general corporate purposes of the joint venture. Under the amended credit facilities, the 5-year Term Loan A facility was reduced to $200 million and the 5-year syndicated revolving credit facility increased to $600 million from $400 million previously, with the maturity of both facilities extended to November 2022. The amended facilities are secured by first-priority perfected liens on substantially all of HIP’s and certain of its wholly-owned subsidiaries’ directly owned assets, including its equity interests in certain subsidiaries, subject to customary exclusions. The 5-year syndicated revolving credit facility is expected to continue to fund the joint venture’s operating activities and capital expenditures. Borrowings under the 5-year Term Loan A facility will generally bear interest at LIBOR plus an applicable margin ranging from 1.55% to 2.50%, while the applicable margin for the 5-year syndicated revolving credit facility ranges from 1.275% to 2.000%. The interest rate continues to be 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 HIP obtains an investment grade credit rating, as defined in the amended credit agreement, pricing levels will be based on the credit ratings in effect from time to time. The joint venture is subject to customary covenants in the credit agreement that include 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 cash interest expense, of no less than 2.25 to 1.0 for the prior four fiscal quarters. The amended credit agreement includes a secured leverage ratio test not to exceed 3.75 to 1.00 for so long as the facilities remain secured. HIP is in compliance with all debt covenants at December 31, 2017, and its financial covenants do not currently impact its ability to issue indebtedness to fund future capital expenditures.

Hess Midstream Partners (the Partnership / HESM):

In 2017, HESM entered into a $300 million 4-year secured syndicated revolving credit facility that can be used for borrowings and letters of credit to fund operating activities and capital expenditures of the Partnership. At December 31, 2017, this facility was undrawn.

Share-based Compensation

12 Months Ended

Dec. 31, 2017

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Share-based Compensation

11. 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, 2017, the total number of authorized common stock under the LTIP, as amended, was 51.5 million shares, of which we have 20.8 million shares available for issuance. Restricted stock generally vests equally on an annual basis over a three-year term while 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. Stock options vest over three years from the date of grant, have a 10‑year term, and the exercise price equals market price on the date of grant.

The number of shares of common stock to be issued under a 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:

	2017		2016		2015
	(In millions)
Restricted stock	$	56	$	45	$	67
Stock options		9		7		5
Performance share units		21		21		25
Share-based compensation expense before income taxes	$	86	$	73	$	97
Income tax benefit on share-based compensation expense	$	1	$	28	$	36

Based on share‑based compensation awards outstanding at December 31, 2017, unearned compensation expense, before income taxes, will be recognized in future years as follows (in millions): 2018—$65, 2019—$34, and 2020—$5.

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, 2017		1,015		$	69.68		6,592		$	67.15		3,101		$	61.93
Granted		439			52.86		662			51.03		1,216			50.98
Exercised		—			—		(152	)		52.75		—			—
Vested		(265	)		90.37		—			—		(729	)		81.06
Forfeited		(43	)		61.23		(620	)		56.66		(386	)		56.72
Outstanding at December 31, 2017		1,146		$	58.78		6,482		$	66.84		3,202		$	54.04

As of December 31, 2017, there were 6.48 million outstanding stock options (5.22 million exercisable) with a weighted average remaining contractual life of 3.6 years (2.3 years for exercisable options) and an aggregated intrinsic value of $2.2 million ($0.8 million for exercisable options). The weighted average exercise price for options exercisable at December 31, 2017 was $70.65 per share.

The following weighted average assumptions were utilized to estimate the fair value of stock options:

	2017			2016			2015
Risk free interest rate		2.17	%		1.47	%		1.77	%
Stock price volatility		0.333			0.326		0.312
Dividend yield		1.96	%		2.26	%		1.34	%
Expected life in years		6.0			6.0			6.0
Weighted average fair value per option granted	$	14.51		$	11.33		$	21.00

The following weighted average assumptions were utilized to estimate the fair value of PSU awards:

	2017			2016			2015
Risk free interest rate		1.55	%		0.96	%		1.02	%
Stock price volatility		0.387		0.329				0.270
Contractual term in years		3.0			3.0			3.0
Grant date price of Hess common stock	$	51.03		$	44.31		$	74.49

The risk-free interest rate is based on the vesting period of the award and is obtained from published sources. The stock price volatility is determined from the historical stock prices of the peer group using the vesting period. The contractual term is equivalent to the vesting period.

Retirement Plans

12 Months Ended

Dec. 31, 2017

Compensation And Retirement Disclosure [Abstract]

Retirement Plans

12. 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
	2017			2016			2017			2016			2017			2016
	(In millions)
Change In Benefit Obligation
Balance at January 1	$	2,560		$	2,321		$	256		$	259		$	84		$	98
Service cost		36			44			13			16			4			4
Interest cost		93			98			9			9			3			3
Actuarial loss (gain) (a)		138			162			10			(5	)		3			(13	)
Benefit payments (b)		(113	)		(132	)		(39	)		(23	)		(7	)		(8	)
Plan curtailments		(3	)		(2	)		—			—			—			—
Special termination benefits		—			1			—			—			—			—
Assumption of HOVENSA pension plan		—			151			—			—			—			—
Foreign currency exchange rate changes		54			(83	)		—			—			—			—
Balance at December 31		2,765			2,560			249			256			87			84
Change In Fair Value of Plan Assets
Balance at January 1	$	2,284		$	2,206		$	—		$	—		$	—		$	—
Actual return on plan assets		351			153			—			—			—			—
Employer contributions		158			26			39			23			7			8
Benefit payments (b)		(113	)		(132	)		(39	)		(23	)		(7	)		(8	)
Assumption of HOVENSA pension plan		—			126			—			—			—			—
Foreign currency exchange rate changes		52			(95	)		—			—			—			—
Balance at December 31		2,732			2,284			—			—			—			—
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	$	(33	)	$	(276	)	$	(249	)	$	(256	)	$	(87	)	$	(84	)
Unrecognized Net Actuarial (Gains) Losses	$	789		$	895		$	84		$	93		$	(10	)	$	(13	)

(a)	The change in discount rate in 2017 resulted in total actuarial losses of approximately $170 million (2016: $175 million).

(b)	Benefit payments include lump-sum settlement payments of $57 million in 2017 (2016: $65 million).

Amounts recognized in the Consolidated Balance Sheet at December 31 consisted of the following:

	Funded						Unfunded						Postretirement
	Pension Plans						Pension Plan						Medical Plan
	2017			2016			2017			2016			2017			2016
	(In millions)
Pension asset / (accrued benefit liability)	$	(33	)	$	(276	)	$	(249	)	$	(256	)	$	(87	)	$	(84	)
Accumulated other comprehensive loss, pre-tax (a)		789			895			84			93			(10	)		(13	)

(a)	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $548 million at December 31, 2017 (2016: $660 million deficit).

At December 31, 2017, the accumulated benefit obligation for the funded and unfunded defined benefit pension plans was $2,679 million and $190 million, respectively (2016: $2,471 million and $203 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
	2017			2016			2015			2017		2016		2015
	(In millions)
Service cost	$	49		$	60		$	67		$	4	$	4	$	4
Interest cost		102			107			102			3		3		3
Expected return on plan assets		(168	)		(166	)		(168	)		—		—		—
Amortization of unrecognized net actuarial losses		58			60			75			—		—		—
Settlement loss		19			—			17			—		—		—
Special termination benefit recognized		—			1			1			—		—		—
Net Periodic Benefit Cost	$	60		$	62		$	94		$	7	$	7	$	7

For our pension and postretirement medical plans in 2018, service cost is estimated to be approximately $55 million, interest cost is estimated to be approximately $90 million, amortization of unrecognized net actuarial losses is estimated to be approximately $50 million, and the estimated expected return on plan assets is estimated to be approximately $195 million.

The weighted average actuarial assumptions used for funded and unfunded pension plans were as follows:

	2017			2016			2015
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate		3.3	%		3.7	%		4.1	%
Rate of compensation increase		4.5	%		4.6	%		4.5	%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31
Discount rate		3.7	%		4.1	%		3.8	%
Expected return on plan assets		7.3	%		7.4	%		7.5	%
Rate of compensation increase		4.6	%		4.5	%		5.0	%

The actuarial assumptions used for postretirement medical plan, as follows:

	2017			2016			2015
Assumptions Used to Determine Benefit Obligations at December 31
Discount rate		3.2	%		3.5	%		3.5	%
Initial health care trend rate		7.3	%		7.7	%		6.7	%
Ultimate trend rate		4.5	%		4.5	%		4.5	%
Year in which ultimate trend rate is reached		2038			2038			2038

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. Beginning in 2018, the Corporation has elected to use a split discount rate approach for all of its retirement plans. This involves the continued use of a single weighted-average discount rate in the calculation of the projected benefit obligation, and separate discount rates for each projected benefit payment in the calculation of service cost and interest cost. In contrast, historically, a single weighted-average discount rate was used in both the calculation of the projected benefit obligation, and service cost and interest cost. This change, which is expected to decrease service cost and interest cost in 2018 by approximately $12 million before income taxes, is a change in accounting estimate that will be applied prospectively.

The overall expected return on plan assets is developed from the expected future returns for each asset category, weighted by the target allocation of pension assets to that asset category. The future expected return assumptions for individual asset categories are largely based on inputs from various investment experts regarding their future return expectations for particular asset categories.

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 us 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, 2017 and 2016 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, 2017
Cash and Short-Term Investment Funds	$	32	$	69	$	—	$	101
Equities:
U.S. equities (domestic)		789		—		—		789
International equities (non-U.S.)		104		330		—		434
Global equities (domestic and non-U.S.)		2		238		—		240
Fixed Income:
Treasury and government issued (a)		—		271		—		271
Government related (b)		—		34		1		35
Mortgage-backed securities (c)		—		166		—		166
Corporate		—		188		—		188
Other:
Hedge funds		—		—		187		187
Private equity funds		—		—		140		140
Real estate funds		63		—		94		157
Diversified commodities funds		—		24		—		24
	$	990	$	1,320	$	422	$	2,732
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

(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, 2016	$	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
Actual return on plan assets		—			3			18			11			32
Purchases, sales or other settlements		—			(25	)		(4	)		31			2
Net transfers in (out) of Level 3		(1	)		—			—			—			(1	)
Balance at December 31, 2017	$	1		$	187		$	140		$	94		$	422

We expect to contribute approximately $44 million to our funded pension plans in 2018.

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):

2018	$	127
2019		142
2020		142
2021		141
2022		145
Years 2023 to 2027		748

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 $22 million in 2017 for contributions to these plans (2016: $25 million; 2015: $28 million).

Exit and Disposal Costs	12 Months Ended
Exit and Disposal Costs	Dec. 31, 2017
Restructuring And Related Activities [Abstract]
Exit and Disposal Costs	13. Exit and Disposal Costs In 2017, we incurred severance expense of $18 million (2016: $55 million; 2015: $13 million) and paid accrued severance costs of $48 million (2016: $52 million; 2015: $57 million). The severance expenses in 2017 resulted from certain asset disposals, as detailed in Note 2, Dispositions. In 2016 and 2015, severance charges related to a realignment of our organization structure communicated in November 2016 and a divestiture program announced in 2013, respectively. Severance charges were based on amounts incurred under ongoing severance arrangements or other statutory requirements, plus amounts earned under enhanced benefit arrangements. We recognized the expense associated with the enhanced benefits ratably over the estimated service period required for the employee to earn the benefit upon termination. In 2017, we incurred other facility and exit related costs of $14 million (2016: $-; 2015: $15 million) and settled $3 millions of these costs (2016: $2 million; 2015: $21 million). The facility and other exit costs related to charges associated with the cessation of use of certain leased office space and contract terminations. At December 31, 2017, we had accrued liabilities for severance costs of $6 million (2016: $36 million) and accrued liabilities for exit costs of $28 million (2016: $17 million). Of the accrued liabilities at December 31, 2017, all severance costs are expected to be paid in 2018 and the exit costs will be paid over the next several years.

Income Taxes

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Income Taxes

14. Income Taxes

The provision (benefit) for income taxes from continuing operations consisted of:

	2017			2016			2015
	(In millions)
United States
Federal
Current	$	(23	)	$	(27	)	$	(7	)
Deferred taxes and other accruals		(6	)		1,948			(995	)
State		—			23			(61	)
		(29	)		1,944			(1,063	)
Foreign
Current		179			36			4
Deferred taxes and other accruals		(1,987	)		235			(231	)
		(1,808	)		271			(227	)
Total		(1,837	)		2,215			(1,290	)
Adjustment of deferred taxes for foreign income tax law changes		—			7			(9	)
Total Provision (Benefit) For Income Taxes (a)	$	(1,837	)	$	2,222		$	(1,299	)

(a)	Includes charges of $3,749 million in 2016 to establish valuation allowances on net deferred tax assets.

Income (loss) from continuing operations before income taxes consisted of the following:

	2017			2016			2015
	(In millions)
United States (a)	$	(2,784	)	$	(2,431	)	$	(2,728	)
Foreign		(2,994	)		(1,423	)		(1,530	)
Total Income (Loss) from Continuing Operations Before Income Taxes	$	(5,778	)	$	(3,854	)	$	(4,258	)

(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:

	2017			2016
	(In millions)
Deferred Tax Liabilities
Property, plant and equipment and investments	$	(629	)	$	(3,810	)
Other		(24	)		(255	)
Total Deferred Tax Liabilities		(653	)		(4,065	)
Deferred Tax Assets
Net operating loss carryforwards		4,029			5,767
Tax credit carryforwards		138			164
Property, plant and equipment and investments		746			834
Accrued compensation, deferred credits and other liabilities		283			526
Asset retirement obligations		212			1,077
Other		36			62
Total Deferred Tax Assets		5,444			8,430
Valuation allowances		(5,199	)		(5,450	)
Total deferred tax assets, net of valuation allowances		245			2,980
Net Deferred Tax Assets (Liabilities)	$	(408	)	$	(1,085	)

At December 31, 2017, we have recognized a gross deferred tax asset related to net operating loss carryforwards of $4,029 million before application of valuation allowances. The deferred tax asset is comprised of $1,386 million attributable to foreign net operating losses which begin to expire in 2024, $2,180 million attributable to U.S. federal operating losses a portion of which begin to expire in 2028, and the majority of which begin to expire in 2034, and $463 million attributable to losses in various U.S. states which began to expire in 2018. The deferred tax asset attributable to foreign net operating losses, net of valuation allowances, is $9 million. A full valuation allowance is established against the deferred tax asset attributable to U.S. federal and state net operating losses. At December 31, 2017, we have U.S. federal, U.S. state and foreign alternative minimum tax credit carryforwards of $53 million, which can be carried forward indefinitely, and approximately $15 million of other business credit carryforwards. The deferred tax asset attributable to these credits, net of valuation allowances, is $4 million. A full valuation allowance is established against our foreign tax credit carryforwards of $70 million, which begin to expire in 2018.

As of December 31, 2017, the Balance Sheet reflects a $5,199 million valuation allowance against the net deferred tax assets for multiple jurisdictions based on application of the relevant accounting standards. Hess continues to maintain a full valuation allowance against its deferred tax assets in the U.S., Denmark (hydrocarbon tax only), Malaysia, and Guyana. 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, 2017 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.

The enactment of U.S. federal tax reform, commonly referred to as the U.S. Tax Cuts and Jobs Act (“Act”), provided for broad changes to the taxation of both domestic and foreign operations. The provisions of the Act, including its extensive transition rules, are complex and interpretive guidance continues to develop. Final application of the Act to our operations and financial results may differ from that for which we have provisionally provided as of December 31, 2017. Changes could arise as regulatory and interpretive action continues to clarify aspects of the Act and as changes are made to estimates that the Corporation has utilized in calculating the transition impacts. No U.S. federal tax has been accrued on the deemed repatriation of unremitted earnings of our foreign subsidiaries. A decrease in the U.S. federal corporate tax rate to 21% from 35% resulted in a $1,476 million reduction to our U.S. federal net deferred tax asset as of December 31, 2017, with a corresponding reduction in the previously established U.S. valuation allowance. A deferred tax liability of $110 million no longer meets the recognition criteria with the transition to a territorial regime for U.S. taxation of foreign earnings and has been derecognized, with a corresponding adjustment to the valuation allowance against the U.S. federal net deferred tax asset. Under the transition rules related to the repeal of the alternative minimum tax regime, an alternative minimum tax credit carryforward of $4 million will be refundable if not used to offset regular tax liability. The previously established valuation allowance against this credit carryforward has been released. Consequently, these tax law changes resulted in a net $4 million increase to net deferred tax asset on the balance sheet and benefit to deferred tax expense.

In the Consolidated Balance Sheet, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:

	2017			2016
	(In millions)
Deferred income taxes (long-term asset)	$	21		$	59
Deferred income taxes (long-term liability)		(429	)		(1,144	)
Net Deferred Tax Assets (Liabilities)	$	(408	)	$	(1,085	)

The difference between our effective income tax rate from continuing operations and the U.S. statutory rate is reconciled below:

	2017				2016				2015
U.S. statutory rate		35.0		%		35.0		%		35.0		%
Effect of foreign operations (a)		17.4				4.6				5.9
State income taxes, net of Federal income tax		—				1.9				0.9
Change in enacted tax laws (b)		(23.6	)			(0.2	)			0.2
Valuation allowance adjustment with tax law change (b)		23.6				—				—
Rate differential on U.S. impairment		(4.1	)			—				—
Gains on asset sales, net		(2.2	)			—				(0.2	)
Impairment		—				(2.1	)			(12.2	)
Valuation allowance on current year operations		(14.9	)			—				—
Valuation allowance against previously benefitted deferred tax assets		0.1				(97.3	)			(3.1	)
Benefit of legal entity restructuring		—				—				3.5
Other		0.5				0.4				0.5
Total		31.8		%		(57.7	)	%		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.

(b)

The enactment of the U.S. Tax Cuts and Jobs Act provided for a decrease in the corporate tax rate to 21% from 35% and a change to a territorial tax regime, resulting in a net $1,366 million reduction to our U.S. net deferred tax asset as of December 31, 2017, with a corresponding reduction in the previously established U.S. valuation allowance.

Below is a reconciliation of the gross beginning and ending amounts of unrecognized tax benefits:

	2017	2016	2015
	(In millions)
Balance at January 1	$424	$604	$603
Additions based on tax positions taken in the current year	14	19	19
Additions based on tax positions of prior years	4	113	29
Reductions based on tax positions of prior years	(147)	(274)	(31)
Reductions due to settlements with taxing authorities	(85)	(27)	(12)
Reductions due to lapses in statutes of limitation	(5)	(11)	(4)
Balance at December 31	$205	$424	$604

The December 31, 2017 balance of unrecognized tax benefits includes $30 million (2016: $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 between $58 million and $139 million due to settlements with taxing authorities or other resolutions, as well as lapses in statutes of limitation. At December 31, 2017, our accrued interest and penalties related to unrecognized tax benefits is $23 million (2016: $29 million).

We are no longer indefinitely reinvested with respect to the book in excess of tax basis in the investment in our foreign subsidiaries. Because of U.S. tax reform we expect that the future reversal of such temporary differences will occur free of material taxation.

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.

Discontinued Operations	12 Months Ended
Discontinued Operations	Dec. 31, 2017
Discontinued Operations And Disposal Groups [Abstract]
Discontinued Operations	15. Discontinued Operations Discontinued operations in the Statement of Consolidated Income and the Statement of Consolidated Cash Flows reflects the results of our ownership in an energy trading partnership through the date of disposal in February 2015, which was part of our former Marketing and Refining segment.

Common and Preferred Stock Issuance	12 Months Ended
Common and Preferred Stock Issuance	Dec. 31, 2017
Stockholders Equity Note [Abstract]
Common and Preferred Stock Issuance	16. 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 are 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.

Outstanding and Weighted Average Common Shares

12 Months Ended

Dec. 31, 2017

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:

	2017			2016		2015
	(In millions)
Balance at January 1		316.5			286.0		285.8
Shares issued		—			28.8		—
Activity related to restricted stock awards, net		0.8			1.1		0.8
Stock options exercised		0.2			0.2		0.2
PSU vested		0.2			0.4		0.6
Shares repurchased (a)		(2.6	)		—		(1.4	)
Balance at December 31		315.1			316.5		286.0

(a)	See Note 18, Share Repurchase Plan.

The following table presents the calculation of basic and diluted earnings per share:

	2017			2016			2015
	(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Income (loss) from continuing operations, net of income taxes	$	(3,941	)	$	(6,076	)	$	(2,959	)
Less: Net income (loss) attributable to noncontrolling interests		133			56			49
Net income (loss) from continuing operations attributable to Hess Corporation		(4,074	)		(6,132	)		(3,008	)
Less: Preferred stock dividends		46			41			—
Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders		(4,120	)		(6,173	)		(3,008	)
Income (loss) from discontinued operations, net of income taxes		—			—			(48	)
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(4,120	)	$	(6,173	)	$	(3,056	)

Weighted Average Number of Common Shares Outstanding:
Basic		314.1			309.9			283.6
Effect of dilutive securities
Restricted common stock		—			—			—
Stock options		—			—			—
Performance share units		—			—			—
Mandatory Convertible Preferred stock		—			—			—
Diluted		314.1			309.9			283.6

Net Income (Loss) Attributable to Hess Corporation per Common Share:
Basic:
Continuing operations	$	(13.12	)	$	(19.92	)	$	(10.61	)
Discontinued operations		—			—			(0.17	)
Net income (loss) per common share	$	(13.12	)	$	(19.92	)	$	(10.78	)
Diluted:
Continuing operations	$	(13.12	)	$	(19.92	)	$	(10.61	)
Discontinued operations		—			—			(0.17	)
Net income (loss) per common share	$	(13.12	)	$	(19.92	)	$	(10.78	)

The following table summarizes the number of antidilutive shares excluded from the computation of diluted shares:

	2017		2016		2015
Antidilutive shares:	(In millions)
Restricted common stock		3.3		3.3		2.9
Stock options		6.4		6.9		6.9
Performance share units		0.6		0.9		1.0
Common shares from conversion of preferred stock		12.8		11.2		—

In 2017, 2016 and 2015, cash dividends declared on common stock totaled $1.00 per share ($0.25 per quarter).

Share Repurchase Plan

12 Months Ended

Dec. 31, 2017

Equity [Abstract]

Share Repurchase Plan

18. Share Repurchase Plan

In March 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:

	2017		2016		2015		To Date
	(In millions, except per share amounts)
Total cost of shares repurchased	$	120	$	—	$	91	$	5,471
Total number of shares repurchased		2.63		—		1.45		66.74
Average cost per share (including transaction fees)	$	45.67	$	—	$	62.76	$	81.96

As of December 31, 2017, we are authorized, but not required, to purchase additional common stock up to a value of $1.03 billion. In 2018, we plan to repurchase approximately $380 million of common stock.

Supplementary Cash Flow Information

12 Months Ended

Dec. 31, 2017

Supplemental Cash Flow Elements [Abstract]

Supplementary Cash Flow Information

19. Supplementary Cash Flow Information

The following information supplements the Statement of Consolidated Cash Flows:

	2017			2016			2015
	(In millions)
Cash Flows From Operating Activities
Interest paid	$	(314	)	$	(338	)	$	(331	)
Net income taxes (paid) refunded		(210	)		132			(140	)

Cash Flows From Investing Activities
Capital expenditures incurred - E&P	$	(1,852	)	$	(1,638	)	$	(3,749	)
Increase (decrease) in related liabilities		64			(336	)		(203	)
Additions to property, plant and equipment - E&P	$	(1,788	)	$	(1,974	)	$	(3,952	)

Capital expenditures incurred - Midstream	$	(121	)	$	(283	)	$	(300	)
Increase (decrease) in related liabilities		(28	)		6			(69	)
Additions to property, plant and equipment - Midstream	$	(149	)	$	(277	)	$	(369	)

Cash Flows From Financing Activities
Contribution from formation of Midstream joint venture		—			—			2,628
Distributions to noncontrolling interests		(243	)		(23	)		(332	)
Noncontrolling interests, net related to Continuing operations	$	(243	)		(23	)		2,296

Leased Assets

12 Months Ended

Dec. 31, 2017

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, 2017, 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):

2018	$	387
2019	376
2020	130
2021	71
2022	70
Remaining years	276
Total Minimum Lease Payments		1,310
Less: Income from subleases	99
Net Minimum Lease Payments	$	1,211

Rental expense was as follows:

	2017		2016		2015
	(In millions)
Total rental expense	$	123	$	106	$	167
Less: Income from subleases	10		5		10
Net Rental Expense	$	113	$	101	$	157

Guarantees, Contingencies and Commitments

12 Months Ended

Dec. 31, 2017

Commitments And Contingencies Disclosure [Abstract]

Guarantees, Contingencies and Commitments

21. Guarantees, Contingencies and Commitments

Guarantees and Contingencies

At December 31, 2017, we have $31 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. There are four remaining active cases, filed by Pennsylvania, Vermont, Rhode Island, and Maryland. 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 alleging that we and other major oil companies damaged the groundwater in Rhode Island by introducing thereto gasoline with MTBE. The suit filed in Rhode Island is proceeding in Federal court. In December 2017, the State of Maryland filed a lawsuit alleging that we and other major oil companies damaged the groundwater in Maryland by introducing thereto gasoline with MTBE. The suit filed in Maryland was filed in state court, but has not been served to date.

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. 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 or the Newark Bay, 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 or the Newark Bay, 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 and connected ship-building and repair facility 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 a neutral expert selected by the parties will determine the final shares of the Remedial Design costs to be paid by each of the participants.

On September 28, 2017, we received a general notice letter and offer to settle from the U.S. Environmental Protection Agency relating to Superfund claims for the Ector Drum, Inc. Superfund Site in Odessa, TX. The EPA and Texas Commission on Environmental Quality (TCEQ) took clean-up and response action at the site commencing in 2014 and concluded in December 2015. The site was determined to have improperly stored industrial waste, including drums with oily liquids. The total clean-up cost incurred by the EPA was approximately $3.5 million. We were invited to negotiate a voluntary settlement for our purported share of the clean-up costs. Our share, if any, is undetermined.

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 the aforementioned proceedings are 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, 2017, which are not included elsewhere within these Consolidated Financial Statements:

			Payments Due by Period
					2019 and		2021 and
	Total		2018		2020		2022		Thereafter
	(In millions)
Capital expenditures	$	1,260	$	563	$	531	$	166	$	—
Operating expenses		412		230		121		39		22
Transportation and related contracts		1,221		210		390		374		247

Segment Information

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

Segment Information

22. Segment Information

We currently have two operating segments, Exploration and Production (E&P) and Midstream. The E&P operating segment explores for, develops, produces, purchases and sells crude oil, natural gas liquids and natural gas. Production operations over the three years ended December 31, 2017 were primarily in the United States (U.S.), Denmark, the JDA and Malaysia, and from divested assets, including Equatorial Guinea and Norway. The 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):


2017	Exploration and Production			Midstream		Corporate, Interest and Other			Eliminations			Total

Operating Revenues - Third-parties	$	5,460		$	6	$	—		$	—		$	5,466
Intersegment Revenues		—			611		—			(611	)		—
Operating Revenues	$	5,460		$	617	$	—		$	(611	)	$	5,466

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(3,653	)	$	42	$	(463	)	$	—		$	(4,074	)
Interest Expense		—			26		299			—			325
Depreciation, Depletion and Amortization		2,736			123		24			—			2,883
Impairment		4,203			—		—			—			4,203
Provision (Benefit) for Income Taxes (a)		(1,842	)		31		(26	)		—			(1,837	)
Investment in Affiliates		134			—		—			—			134
Identifiable Assets		15,613			3,329		4,170			—			23,112
Capital Expenditures		1,852			121		—			—			1,973

2016

Operating Revenues - Third-parties	$	4,755		$	7	$	—		$	—		$	4,762
Intersegment Revenues		—			562		—			(562	)		—
Operating Revenues	$	4,755		$	569	$	—		$	(562	)	$	4,762

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(4,964	)	$	42	$	(1,210	)	$	—		$	(6,132	)
Interest Expense		—			19		319			—			338
Depreciation, Depletion and Amortization		3,113			121		10			—			3,244
Impairment		—			67		—			—			67
Provision (Benefit) for Income Taxes		1,587			26		609			—			2,222
Investment in Affiliates		146			—		—			—			146
Identifiable Assets		22,856			3,165		2,600			—			28,621
Capital Expenditures		1,638			283		—			—			1,921

2015

Operating Revenues - Third-parties	$	6,627		$	9	$	—		$	—		$	6,636
Intersegment Revenues		—			625		—			(625	)		—
Operating Revenues	$	6,627		$	634	$	—		$	(625	)	$	6,636

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(2,727	)	$	96	$	(377	)	$	—		$	(3,008	)
Interest Expense		—			10		331			—			341
Depreciation, Depletion and Amortization		3,833			107		15			—			3,955
Impairment		1,616			—		—			—			1,616
Provision (Benefit) for Income Taxes		(1,117	)		58		(240	)		—			(1,299	)
Capital Expenditures		3,749			300		—			—			4,049

(a)	The provision for income taxes in the Midstream segment in 2017 is presented before consolidating its operations with other U.S. activities of the Company and prior to evaluating realizability of net U.S. deferred taxes. An offsetting impact is presented in the E&P segment.

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)
2017
Operating revenues	$	3,692		$	629		$	675		$	470		$	—		$	5,466
Net income (loss) from continuing operations attributable to Hess Corporation		(2,433	)		(1,383	)		259			(54	)		(463	)		(4,074	)
Depreciation, depletion and amortization		1,942			381			263			273			24			2,883
Impairment		1,700			2,503			—			—			—			4,203
Provision (benefit) for income taxes		—			(1,999	)		197			(9	)		(26	)		(1,837	)
Identifiable assets		13,640			1,024			428			3,850			4,170			23,112
Property, plant and equipment (net)		11,894			946			365			2,964			23			16,192
Capital expenditures		1,387			141			30			415			—			1,973
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	)
Capital expenditures		2,727			297			160			865			—			4,049

(a)	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

Financial Risk Management Activities

12 Months Ended

Dec. 31, 2017

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Financial Risk Management Activities

23. 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 activities 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. At December 31, 2017, these forward contracts relate to the British Pound. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates and, in the case of certain long-term debt relating to our Midstream operating segment, from floating to fixed 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:

	2017		2016
	(In millions)
Commodity - crude oil (millions of barrels)		42		—
Foreign exchange	$	52	$	785
Interest rate swaps	$	450	$	350

At December 31, 2017, we have outstanding West Texas Intermediate (WTI) crude oil collar contracts with a notional amount of 115,000 bopd for 2018 with an average monthly floor price of $50 per barrel and an average monthly ceiling price of $65 per barrel. Contracts with a notional amount of 90,000 bopd are designated as cash flow hedges, while 25,000 bopd were de-designated as cash flow hedges following the shutdown of a third-party operated offshore platform as a result of a fire in the fourth quarter of 2017.

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:

	Assets			Liabilities
	(In millions)
December 31, 2017
Derivative Contracts Designated as Hedging Instruments
Commodity - Accounts payable	$	—		$	(7	)
Interest rate - Other assets (noncurrent) and Accounts payable		—			(4	)
Total derivative contracts designated as hedging instruments		—			(11	)
Derivative Contracts Not Designated as Hedging Instruments
Commodity - Accounts payable		—			(2	)
Foreign exchange		1			—
Total derivative contracts not designated as hedging instruments		1			(2	)
Gross fair value of derivative contracts		1			(13	)
Net Fair Value of Derivative Contracts	$	1		$	(13	)

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 - Accounts receivable and Accrued liabilities		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		$	—

Income statement impact of derivative contracts designated as hedging instruments:

Crude oil collars: In 2017, crude oil price hedging contracts decreased Sales and other operating revenues by $34 million (2016: $-; 2015: increase of $126 million). This amount includes a loss of $71 million associated with changes in the time value of crude oil collars (2016: $-; 2015: losses of $48 million), and a charge of $1 million for hedge ineffectiveness (2016: $-; 2015: $-). At December 31, 2017, after-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding hedged crude oil collars were $127 million, of which all will be reclassified into earnings during the next 12 months as the hedged crude oil sales are recognized in earnings. There were no crude oil hedge contracts in 2016.

Interest rate swaps designated as fair value hedges: At December 31, 2017, we had interest rate swaps with gross notional amounts of $450 million (2016: $350 million), which were designated as fair value hedges and relate to debt where we have converted interest payments on certain long-term debt from fixed to floating rates. 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 2017, the change in fair value of interest rate swaps was an increase in the derivative liability of $4 million (2016: $6 million increase in asset; 2015: $4 million increase in asset) with a corresponding adjustment in the carrying value of the hedged fixed‑rate debt. In February 2018, we terminated interest rate swaps with a gross notional amount of $350 million. See Note 24, Subsequent Events.

Interest rate swaps designated as cash flow hedges: At December 31, 2017, there were no outstanding interest rate swaps designated as cash flow hedges. During 2017, HIP entered into interest rate swaps with gross notional amounts totaling $553 million to convert interest payments on certain long-term debt from floating to fixed rates before settling these instruments as part of the refinancing that occurred later in the year. See Note 10, Debt. In 2017, the change in fair value of interest rate swaps was an increase to assets of $3 million and the cash settlement was $3 million. At December 31, 2017, after-tax deferred income in Accumulated other comprehensive income (loss) in connection with the settled instruments, was $1 million, of which all will be reclassified into earnings during the next 12 months.

Income statement impact of derivative contracts not designated as hedging instruments:

Crude oil collars: In 2017, noncash adjustments to de-designated crude oil price hedging contracts decreased Sales and other operating revenues by $25 million. At December 31, 2017, after-tax deferred losses in Accumulated other comprehensive income (loss) in connection with the de-designation, were $12 million, of which all will be reclassified into earnings during the next 12 months as the originally hedged crude oil sales are recognized in earnings.

Foreign exchange: Total foreign exchange gains and losses were a gain of $15 million in 2017 (2016: gain of $26 million; 2015: loss of $21 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 $3 million in 2017 (2016: gain of $62 million; 2015: gain of $98 million).

In 2017, after‑tax foreign currency translation adjustments included in the Statement of Consolidated Comprehensive Income amounted to a gain of $144 million (2016: gain of $56 million; 2015: loss of $344 million) and $900 million of cumulative currency translation losses that were recognized in earnings as a result of the sale of our assets in Norway. See Note 2, Dispositions. Cumulative currency translation adjustments reduced stockholders’ equity by $1,044 million at December 31, 2016.

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, 2017, our Accounts receivable—Trade were concentrated with the following counterparty industry segments: Integrated companies — 50%, Refining and marketing companies — 17%, Independent E&P companies — 14%, Storage and transportation companies — 7%, National oil companies — 2% and Others — 10%. 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, 2017, we had outstanding letters of credit totaling $246 million (2016: $188 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, 2017 and December 31, 2016. In addition, the disclosure for fair value of long-term debt in Note 10, Debt was based on Level 2 inputs.

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued) 24. Subsequent Events In January 2018, we eliminated approximately 300 employee positions as part of a cost reduction program following the 2017 asset sales. We expect to record employee severance costs of $40 million to $50 million in the first quarter of 2018. On February 15, 2018, Hess Corporation redeemed $350 million principal amount of 8.125% notes due 2019 for $370 million. The carrying value of these notes, which are included in Current maturities of long-term debt in the Consolidated Balance Sheet, was $349 million at December 31, 2017. Concurrent with the redemption, the Corporation terminated interest rate swaps with a notional amount of $350 million, which were previously designated as fair value hedges of these notes. On February 16, 2018, we entered into an agreement to sell our interests in Ghana for total consideration of $100 million, consisting of a $25 million payment upon closing and a further payment of $75 million payable upon approval of the Plan of Development on the Deepwater Tano Cape Three Points block. The transaction is subject to government approval and customary closing conditions.

Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2017

Valuation And Qualifying Accounts [Abstract]

Valuation and Qualifying Accounts

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

VALUATION AND QUALIFYING ACCOUNTS

For the Years Ended December 31, 2017, 2016 and 2015

					Additions
Description	Balance January 1		Charged to Costs and Expenses			Charged to Other Accounts		Deductions from Reserves		Balance December 31
		(In millions)
2017
Losses on receivables	$	8	$	1		$	—	$	—	$	9
Deferred income tax valuation	$	5,450	$	1,214		$	—	$	1,465	$	5,199
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

Nature of Operations, Basis of Presentation and Summary of Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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. See Note 7, Hess Infrastructure Partners LP. Our undivided interests in unincorporated oil and gas E&P 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 2017, we adopted Accounting Standards Update (ASU) 2016-16, Income Taxes – Intra-Entity Transfer of Assets Other than Inventory. This ASU requires the recognition of income tax consequences from intra-entity transfer of assets other than inventory when the transfer occurs. The adoption of this standard was applied on a modified retrospective basis through a cumulative effect adjustment as of January 1, 2017, that resulted in a decrease to Retained earnings and a decrease to Deferred income taxes, included in non-current assets, of $37 million. In 2017, we adopted 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, the presentation of the statements of cash flow, and the consideration of net settlement provisions on the balance sheet classification of the share-based award. As part of the adoption of this ASU, we elected to account for forfeitures of share-based awards in the period when they occur. The effect of this election was applied on a modified retrospective basis through a cumulative effect adjustment as of January 1, 2017, that resulted in a decrease to Retained earnings and an increase to Capital in excess of par value of $2 million. The cumulative effect adjustment to deferred tax assets for excess tax benefits not previously recognized as of the beginning of the period was offset by a corresponding change in valuation allowance, resulting in no cumulative effect adjustment to Retained earnings. Further, as part of the adoption of this ASU, we have applied its provisions affecting excess tax benefits on a prospective basis in the statement of income and the statement of cash flows, effective January 1, 2017.
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	HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 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 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	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. The costs of exploratory wells that find oil and gas reserves are capitalized pending determination of whether proved reserves have been found. Exploratory drilling costs remain capitalized after drilling is completed if (1) the well has found a sufficient quantity of reserves to justify completion as a producing well and (2) sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If either of those criteria is not met, or if there is substantial doubt about the economic or operational viability of a project, the capitalized well costs are charged to expense. Indicators of sufficient progress in assessing reserves and the economic and operating viability of a project include commitment of project personnel, active negotiations for sales contracts with customers, negotiations with governments, operators and contractors, firm plans for additional drilling and other factors.
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization: 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 impairment 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 3, 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.
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 are no longer indefinitely reinvested with respect to the book in excess of tax basis in the investment in our foreign subsidiaries. Because of U.S. tax reform we expect that the future reversal of such temporary differences will occur free of material taxation. We classify interest and penalties associated with uncertain tax positions as income tax expense. We account for the U.S. tax effect of global intangible low-taxed income earned by foreign subsidiaries in the period that such income is earned.
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 E&P 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 over the service period for the entire award, whether the award was granted with ratable or cliff vesting, net of actual forfeitures. 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 our 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 our former operations in Norway that did not use the U.S. Dollar as the functional currency, adjustments resulting from translating foreign currency assets and liabilities into U.S. Dollars were recorded in the Consolidated Balance Sheet in a separate component of equity titled Accumulated other comprehensive income (loss) prior to the disposition. See Note 2, Dispositions.
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 2017, 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. Our analysis of contracts with customers against the requirements of ASC 606 is complete and we have not identified any changes to the timing of revenue recognition based on requirements of the standard that would have a material impact on our consolidated financial statements. We will 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, if any, 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 Consolidated 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 have developed and are executing a project plan for the implementation of ASC 842 in the first quarter of 2019. We are progressing our assessment of existing leases and evaluating our disclosure processes with reference to the requirements of the standard. We continue to assess the impact of the ASU 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 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. Application of this ASU is on a prospective basis only when adopted. 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. In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits. This ASU requires that an employer disaggregate the service cost component from the other components of net periodic benefit cost. The amendments also provide explicit guidance on how to present the service cost component and the other components of net periodic benefit cost in the statement of income and allow only the service cost component of net periodic benefit cost to be eligible for capitalization. This ASU is effective for us beginning in the first quarter of 2018. We are currently assessing the impact of the ASU on our consolidated financial statements. In August 2017, FASB issued ASU 2017-12, Derivatives and Hedging – Targeted Improvements to Accounting for Hedging Activities. This ASU aims to improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. In addition, this ASU make certain targeted improvements to simplify the application of the existing hedge accounting guidance. This ASU is effective for us beginning in the first quarter of 2019, with early application permitted. We plan to adopt this ASU in the first quarter of 2018 and expect the impact of adoption to our consolidated financial statements to be immaterial.

Disposition (Tables)

12 Months Ended

Dec. 31, 2017

Disposition Of Businesses [Abstract]

Schedule of Pre-tax Income (Loss) Associated with Interests Excluding Financial Statement Impacts Resulting from Asset Sales

	2017			2016			2015
	(In millions)
Equatorial Guinea (a)	$	69		$	(95	)	$	(23	)
Norway (b)		(55	)		(195	)		(276	)
Income (Loss) from Continuing Operations Before Income Taxes	$	14		$	(290	)	$	(299	)

(a)	Pre-tax income for 2017 excludes the gain of $486 million related to sale of our assets in November 2017.

(b)	Pre-tax loss for 2017 excludes the loss of $857 million related to sale of our assets in December 2017. In addition, the 2017 loss excludes a pre-tax impairment charge of $2,503 million associated with the disposition.

Inventories (Tables)

12 Months Ended

Dec. 31, 2017

Inventory Disclosure [Abstract]

Inventories

Inventories at December 31 were as follows:

	2017		2016
	(In millions)
Crude oil and natural gas liquids	$	59	$	77
Materials and supplies		173		246
Total Inventories	$	232	$	323

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2017

Property Plant And Equipment [Abstract]

Components of Property, Plant and Equipment

Property, plant and equipment at December 31 were as follows:

	2017		2016
	(In millions)
Exploration and Production
Unproved properties	$	520	$	710
Proved properties		3,162		4,249
Wells, equipment and related facilities		25,550		38,250
		29,232		43,209
Midstream		3,219		3,598
Corporate and Other		53		100
Total — at cost		32,504		46,907
Less: Reserves for depreciation, depletion, amortization and lease impairment		16,312		23,312
Property, Plant and Equipment — Net	$	16,192	$	23,595

Net Changes in Capitalized Exploratory Well Costs

	2017			2016			2015
	(In millions)
Balance at January 1	$	597		$	1,415		$	1,416
Additions to capitalized exploratory well costs pending the determination of proved reserves		116			79			424
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(165	)		—			(72	)
Capitalized exploratory well costs charged to expense		(268	)		(897	)		(356	)
Dispositions and other		24			—			3
Balance at December 31	$	304		$	597		$	1,415
Number of Wells at December 31		12			17			35

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 $170 million at December 31, 2017, separated by year of completion as follows (in millions):

2016	$	—
2015		166
2014		—
2013		4
	$	170

Goodwill (Tables)

12 Months Ended

Dec. 31, 2017

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		Midstream			Total
	(In millions)
Balance at December 31, 2016	$	—	$	375		$	375
Dispositions		—		(15	)		(15	)
Balance at December 31, 2017	$	—	$	360		$	360

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2017

Asset Retirement Obligation Disclosure [Abstract]

Changes to Asset Retirement Obligations

The following table describes changes to our asset retirement obligations:

	2017			2016
	(In millions)
Balance at January 1	$	2,128		$	2,383
Liabilities incurred		62			42
Liabilities settled or disposed of		(1,464	)		(196	)
Accretion expense		97			117
Revisions of estimated liabilities		(54	)		(230	)
Foreign currency translation		32			12
Balance at December 31		801			2,128
Less: Current Obligations		48			216
Long-term Obligations at end of period	$	753		$	1,912

Debt (Tables)

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Components of Debt

Long‑term debt at December 31 consisted of the following:

	2017		2016
	(In millions)
Debt - Hess Corporation:
Fixed-rate public notes:
8.1% due 2019	$	349	$	349
3.5% due 2024		297		297
4.3% due 2027		991		989
7.9% due 2029		500		499
7.3% due 2031		679		679
7.1% due 2033		596		596
6.0% due 2040		740		740
5.6% due 2041		1,234		1,232
5.8% due 2047		493		493
Total fixed-rate public notes		5,879		5,874
Financing obligations associated with floating production system		118		192
Fair value adjustments - interest rate hedging		—		7
Total Debt - Hess Corporation	$	5,997	$	6,073

Debt - Midstream
Fixed-rate notes: 5.6% due 2026 - HIP	$	785	$	—
Term loan A facility - HIP		195		580
Revolving credit facility - HIP		—		153
Revolving credit facility - HESM		—		—
Total Debt - Midstream	$	980	$	733

Total Long-Term Debt:
Total debt (a)	$	6,977	$	6,806
Less: Current maturities of long-term debt		580		112
Total Long-Term Debt	$	6,397	$	6,694

(a)	At December 31, 2017 the fair value of total debt amounted to $7,718 million (2016: $7,548 million).

Maturity Profile of Total Debt

At December 31, 2017, the maturity profile of total debt was as follows:

	Total		Hess Corporation		Midstream
	(In millions)

2018	$	580	$	578	$	2
2019		51		40		11
2020		15		—		15
2021		16		—		16
2022		151		—		151
Thereafter		6,164		5,379		785
Total debt (excluding interest)	$	6,977	$	5,997	$	980

Other Outstanding Letters of Credit

Other outstanding letters of credit at December 31 were as follows:

	2017		2016
	(In millions)
Committed lines (a)	$	29	$	1
Uncommitted lines (a)		217		187
Total (b)	$	246	$	188

(a)	At December 31, 2017, committed and uncommitted lines have expiration dates through 2018.

(b)	At December 31, 2017, total outstanding letters of credit includes $215 million related to liabilities recorded in the Consolidated Balance Sheet (2016: $161 million).

Share-based Compensation (Tables)

12 Months Ended

Dec. 31, 2017

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Share-based Compensation Expense

Share‑based compensation expense consisted of the following:

	2017		2016		2015
	(In millions)
Restricted stock	$	56	$	45	$	67
Stock options		9		7		5
Performance share units		21		21		25
Share-based compensation expense before income taxes	$	86	$	73	$	97
Income tax benefit on share-based compensation expense	$	1	$	28	$	36

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, 2017		1,015		$	69.68		6,592		$	67.15		3,101		$	61.93
Granted		439			52.86		662			51.03		1,216			50.98
Exercised		—			—		(152	)		52.75		—			—
Vested		(265	)		90.37		—			—		(729	)		81.06
Forfeited		(43	)		61.23		(620	)		56.66		(386	)		56.72
Outstanding at December 31, 2017		1,146		$	58.78		6,482		$	66.84		3,202		$	54.04

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:

	2017			2016			2015
Risk free interest rate		2.17	%		1.47	%		1.77	%
Stock price volatility		0.333			0.326		0.312
Dividend yield		1.96	%		2.26	%		1.34	%
Expected life in years		6.0			6.0			6.0
Weighted average fair value per option granted	$	14.51		$	11.33		$	21.00

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:

	2017			2016			2015
Risk free interest rate		1.55	%		0.96	%		1.02	%
Stock price volatility		0.387		0.329				0.270
Contractual term in years		3.0			3.0			3.0
Grant date price of Hess common stock	$	51.03		$	44.31		$	74.49

Retirement Plans (Tables)

12 Months Ended

Dec. 31, 2017

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
	2017			2016			2017			2016			2017			2016
	(In millions)
Change In Benefit Obligation
Balance at January 1	$	2,560		$	2,321		$	256		$	259		$	84		$	98
Service cost		36			44			13			16			4			4
Interest cost		93			98			9			9			3			3
Actuarial loss (gain) (a)		138			162			10			(5	)		3			(13	)
Benefit payments (b)		(113	)		(132	)		(39	)		(23	)		(7	)		(8	)
Plan curtailments		(3	)		(2	)		—			—			—			—
Special termination benefits		—			1			—			—			—			—
Assumption of HOVENSA pension plan		—			151			—			—			—			—
Foreign currency exchange rate changes		54			(83	)		—			—			—			—
Balance at December 31		2,765			2,560			249			256			87			84
Change In Fair Value of Plan Assets
Balance at January 1	$	2,284		$	2,206		$	—		$	—		$	—		$	—
Actual return on plan assets		351			153			—			—			—			—
Employer contributions		158			26			39			23			7			8
Benefit payments (b)		(113	)		(132	)		(39	)		(23	)		(7	)		(8	)
Assumption of HOVENSA pension plan		—			126			—			—			—			—
Foreign currency exchange rate changes		52			(95	)		—			—			—			—
Balance at December 31		2,732			2,284			—			—			—			—
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	$	(33	)	$	(276	)	$	(249	)	$	(256	)	$	(87	)	$	(84	)
Unrecognized Net Actuarial (Gains) Losses	$	789		$	895		$	84		$	93		$	(10	)	$	(13	)

(a)	The change in discount rate in 2017 resulted in total actuarial losses of approximately $170 million (2016: $175 million).

(b)	Benefit payments include lump-sum settlement payments of $57 million in 2017 (2016: $65 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
	2017			2016			2017			2016			2017			2016
	(In millions)
Pension asset / (accrued benefit liability)	$	(33	)	$	(276	)	$	(249	)	$	(256	)	$	(87	)	$	(84	)
Accumulated other comprehensive loss, pre-tax (a)		789			895			84			93			(10	)		(13	)

(a)	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $548 million at December 31, 2017 (2016: $660 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
	2017			2016			2015			2017		2016		2015
	(In millions)
Service cost	$	49		$	60		$	67		$	4	$	4	$	4
Interest cost		102			107			102			3		3		3
Expected return on plan assets		(168	)		(166	)		(168	)		—		—		—
Amortization of unrecognized net actuarial losses		58			60			75			—		—		—
Settlement loss		19			—			17			—		—		—
Special termination benefit recognized		—			1			1			—		—		—
Net Periodic Benefit Cost	$	60		$	62		$	94		$	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:

	2017			2016			2015
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate		3.3	%		3.7	%		4.1	%
Rate of compensation increase		4.5	%		4.6	%		4.5	%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31
Discount rate		3.7	%		4.1	%		3.8	%
Expected return on plan assets		7.3	%		7.4	%		7.5	%
Rate of compensation increase		4.6	%		4.5	%		5.0	%

The actuarial assumptions used for postretirement medical plan, as follows:

	2017			2016			2015
Assumptions Used to Determine Benefit Obligations at December 31
Discount rate		3.2	%		3.5	%		3.5	%
Initial health care trend rate		7.3	%		7.7	%		6.7	%
Ultimate trend rate		4.5	%		4.5	%		4.5	%
Year in which ultimate trend rate is reached		2038			2038			2038

Fair Value of Financial Assets of Funded Pension Plans

	Level 1		Level 2		Level 3		Total
	(In millions)
December 31, 2017
Cash and Short-Term Investment Funds	$	32	$	69	$	—	$	101
Equities:
U.S. equities (domestic)		789		—		—		789
International equities (non-U.S.)		104		330		—		434
Global equities (domestic and non-U.S.)		2		238		—		240
Fixed Income:
Treasury and government issued (a)		—		271		—		271
Government related (b)		—		34		1		35
Mortgage-backed securities (c)		—		166		—		166
Corporate		—		188		—		188
Other:
Hedge funds		—		—		187		187
Private equity funds		—		—		140		140
Real estate funds		63		—		94		157
Diversified commodities funds		—		24		—		24
	$	990	$	1,320	$	422	$	2,732
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

(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, 2016	$	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
Actual return on plan assets		—			3			18			11			32
Purchases, sales or other settlements		—			(25	)		(4	)		31			2
Net transfers in (out) of Level 3		(1	)		—			—			—			(1	)
Balance at December 31, 2017	$	1		$	187		$	140		$	94		$	422

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):

2018	$	127
2019		142
2020		142
2021		141
2022		145
Years 2023 to 2027		748

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Components of Income Tax Provision (Benefit) for Continuing Operations

The provision (benefit) for income taxes from continuing operations consisted of:

	2017			2016			2015
	(In millions)
United States
Federal
Current	$	(23	)	$	(27	)	$	(7	)
Deferred taxes and other accruals		(6	)		1,948			(995	)
State		—			23			(61	)
		(29	)		1,944			(1,063	)
Foreign
Current		179			36			4
Deferred taxes and other accruals		(1,987	)		235			(231	)
		(1,808	)		271			(227	)
Total		(1,837	)		2,215			(1,290	)
Adjustment of deferred taxes for foreign income tax law changes		—			7			(9	)
Total Provision (Benefit) For Income Taxes (a)	$	(1,837	)	$	2,222		$	(1,299	)

(a)	Includes charges of $3,749 million in 2016 to establish valuation allowances on net deferred tax assets.

Income (Loss) From Continuing Operations Before Income Taxes

Income (loss) from continuing operations before income taxes consisted of the following:

	2017			2016			2015
	(In millions)
United States (a)	$	(2,784	)	$	(2,431	)	$	(2,728	)
Foreign		(2,994	)		(1,423	)		(1,530	)
Total Income (Loss) from Continuing Operations Before Income Taxes	$	(5,778	)	$	(3,854	)	$	(4,258	)

(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:

	2017			2016
	(In millions)
Deferred Tax Liabilities
Property, plant and equipment and investments	$	(629	)	$	(3,810	)
Other		(24	)		(255	)
Total Deferred Tax Liabilities		(653	)		(4,065	)
Deferred Tax Assets
Net operating loss carryforwards		4,029			5,767
Tax credit carryforwards		138			164
Property, plant and equipment and investments		746			834
Accrued compensation, deferred credits and other liabilities		283			526
Asset retirement obligations		212			1,077
Other		36			62
Total Deferred Tax Assets		5,444			8,430
Valuation allowances		(5,199	)		(5,450	)
Total deferred tax assets, net of valuation allowances		245			2,980
Net Deferred Tax Assets (Liabilities)	$	(408	)	$	(1,085	)

In the Consolidated Balance Sheet, deferred tax assets and liabilities are netted by taxing jurisdiction and are recorded at December 31 as follows:

	2017			2016
	(In millions)
Deferred income taxes (long-term asset)	$	21		$	59
Deferred income taxes (long-term liability)		(429	)		(1,144	)
Net Deferred Tax Assets (Liabilities)	$	(408	)	$	(1,085	)

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:

	2017				2016				2015
U.S. statutory rate		35.0		%		35.0		%		35.0		%
Effect of foreign operations (a)		17.4				4.6				5.9
State income taxes, net of Federal income tax		—				1.9				0.9
Change in enacted tax laws (b)		(23.6	)			(0.2	)			0.2
Valuation allowance adjustment with tax law change (b)		23.6				—				—
Rate differential on U.S. impairment		(4.1	)			—				—
Gains on asset sales, net		(2.2	)			—				(0.2	)
Impairment		—				(2.1	)			(12.2	)
Valuation allowance on current year operations		(14.9	)			—				—
Valuation allowance against previously benefitted deferred tax assets		0.1				(97.3	)			(3.1	)
Benefit of legal entity restructuring		—				—				3.5
Other		0.5				0.4				0.5
Total		31.8		%		(57.7	)	%		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:

	2017	2016	2015
	(In millions)
Balance at January 1	$424	$604	$603
Additions based on tax positions taken in the current year	14	19	19
Additions based on tax positions of prior years	4	113	29
Reductions based on tax positions of prior years	(147)	(274)	(31)
Reductions due to settlements with taxing authorities	(85)	(27)	(12)
Reductions due to lapses in statutes of limitation	(5)	(11)	(4)
Balance at December 31	$205	$424	$604

Outstanding and Weighted Average Common Shares (Tables)

12 Months Ended

Dec. 31, 2017

Earnings Per Share [Abstract]

Changes in Outstanding Common Shares

The following table provides the changes in our outstanding common shares:

	2017			2016		2015
	(In millions)
Balance at January 1		316.5			286.0		285.8
Shares issued		—			28.8		—
Activity related to restricted stock awards, net		0.8			1.1		0.8
Stock options exercised		0.2			0.2		0.2
PSU vested		0.2			0.4		0.6
Shares repurchased (a)		(2.6	)		—		(1.4	)
Balance at December 31		315.1			316.5		286.0

(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:

	2017			2016			2015
	(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Income (loss) from continuing operations, net of income taxes	$	(3,941	)	$	(6,076	)	$	(2,959	)
Less: Net income (loss) attributable to noncontrolling interests		133			56			49
Net income (loss) from continuing operations attributable to Hess Corporation		(4,074	)		(6,132	)		(3,008	)
Less: Preferred stock dividends		46			41			—
Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders		(4,120	)		(6,173	)		(3,008	)
Income (loss) from discontinued operations, net of income taxes		—			—			(48	)
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(4,120	)	$	(6,173	)	$	(3,056	)

Weighted Average Number of Common Shares Outstanding:
Basic		314.1			309.9			283.6
Effect of dilutive securities
Restricted common stock		—			—			—
Stock options		—			—			—
Performance share units		—			—			—
Mandatory Convertible Preferred stock		—			—			—
Diluted		314.1			309.9			283.6

Net Income (Loss) Attributable to Hess Corporation per Common Share:
Basic:
Continuing operations	$	(13.12	)	$	(19.92	)	$	(10.61	)
Discontinued operations		—			—			(0.17	)
Net income (loss) per common share	$	(13.12	)	$	(19.92	)	$	(10.78	)
Diluted:
Continuing operations	$	(13.12	)	$	(19.92	)	$	(10.61	)
Discontinued operations		—			—			(0.17	)
Net income (loss) per common share	$	(13.12	)	$	(19.92	)	$	(10.78	)

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:

	2017		2016		2015
Antidilutive shares:	(In millions)
Restricted common stock		3.3		3.3		2.9
Stock options		6.4		6.9		6.9
Performance share units		0.6		0.9		1.0
Common shares from conversion of preferred stock		12.8		11.2		—

Share Repurchase Plan (Tables)

12 Months Ended

Dec. 31, 2017

Equity [Abstract]

Schedule of Share Repurchases Under Share Repurchase Plan

Repurchases under this program to date have been as follows:

	2017		2016		2015		To Date
	(In millions, except per share amounts)
Total cost of shares repurchased	$	120	$	—	$	91	$	5,471
Total number of shares repurchased		2.63		—		1.45		66.74
Average cost per share (including transaction fees)	$	45.67	$	—	$	62.76	$	81.96

Supplementary Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2017

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:

	2017			2016			2015
	(In millions)
Cash Flows From Operating Activities
Interest paid	$	(314	)	$	(338	)	$	(331	)
Net income taxes (paid) refunded		(210	)		132			(140	)

Cash Flows From Investing Activities
Capital expenditures incurred - E&P	$	(1,852	)	$	(1,638	)	$	(3,749	)
Increase (decrease) in related liabilities		64			(336	)		(203	)
Additions to property, plant and equipment - E&P	$	(1,788	)	$	(1,974	)	$	(3,952	)

Capital expenditures incurred - Midstream	$	(121	)	$	(283	)	$	(300	)
Increase (decrease) in related liabilities		(28	)		6			(69	)
Additions to property, plant and equipment - Midstream	$	(149	)	$	(277	)	$	(369	)

Cash Flows From Financing Activities
Contribution from formation of Midstream joint venture		—			—			2,628
Distributions to noncontrolling interests		(243	)		(23	)		(332	)
Noncontrolling interests, net related to Continuing operations	$	(243	)		(23	)		2,296

Leased Assets (Tables)

12 Months Ended

Dec. 31, 2017

Leases [Abstract]

Future Minimum Rental Payments

At December 31, 2017, 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):

2018	$	387
2019	376
2020	130
2021	71
2022	70
Remaining years	276
Total Minimum Lease Payments		1,310
Less: Income from subleases	99
Net Minimum Lease Payments	$	1,211

Rental Expense

Rental expense was as follows:

	2017		2016		2015
	(In millions)
Total rental expense	$	123	$	106	$	167
Less: Income from subleases	10		5		10
Net Rental Expense	$	113	$	101	$	157

Guarantees, Contingencies and Commitments (Tables)

12 Months Ended

Dec. 31, 2017

Commitments And Contingencies Disclosure [Abstract]

Schedule of Unconditional Purchase Obligations and Commitments

			Payments Due by Period
					2019 and		2021 and
	Total		2018		2020		2022		Thereafter
	(In millions)
Capital expenditures	$	1,260	$	563	$	531	$	166	$	—
Operating expenses		412		230		121		39		22
Transportation and related contracts		1,221		210		390		374		247

Segment Information (Tables)

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

Financial Data by Operating Segment

The following table presents operating segment financial data for continuing operations (in millions):


2017	Exploration and Production			Midstream		Corporate, Interest and Other			Eliminations			Total

Operating Revenues - Third-parties	$	5,460		$	6	$	—		$	—		$	5,466
Intersegment Revenues		—			611		—			(611	)		—
Operating Revenues	$	5,460		$	617	$	—		$	(611	)	$	5,466

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(3,653	)	$	42	$	(463	)	$	—		$	(4,074	)
Interest Expense		—			26		299			—			325
Depreciation, Depletion and Amortization		2,736			123		24			—			2,883
Impairment		4,203			—		—			—			4,203
Provision (Benefit) for Income Taxes (a)		(1,842	)		31		(26	)		—			(1,837	)
Investment in Affiliates		134			—		—			—			134
Identifiable Assets		15,613			3,329		4,170			—			23,112
Capital Expenditures		1,852			121		—			—			1,973

2016

Operating Revenues - Third-parties	$	4,755		$	7	$	—		$	—		$	4,762
Intersegment Revenues		—			562		—			(562	)		—
Operating Revenues	$	4,755		$	569	$	—		$	(562	)	$	4,762

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(4,964	)	$	42	$	(1,210	)	$	—		$	(6,132	)
Interest Expense		—			19		319			—			338
Depreciation, Depletion and Amortization		3,113			121		10			—			3,244
Impairment		—			67		—			—			67
Provision (Benefit) for Income Taxes		1,587			26		609			—			2,222
Investment in Affiliates		146			—		—			—			146
Identifiable Assets		22,856			3,165		2,600			—			28,621
Capital Expenditures		1,638			283		—			—			1,921

2015

Operating Revenues - Third-parties	$	6,627		$	9	$	—		$	—		$	6,636
Intersegment Revenues		—			625		—			(625	)		—
Operating Revenues	$	6,627		$	634	$	—		$	(625	)	$	6,636

Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	$	(2,727	)	$	96	$	(377	)	$	—		$	(3,008	)
Interest Expense		—			10		331			—			341
Depreciation, Depletion and Amortization		3,833			107		15			—			3,955
Impairment		1,616			—		—			—			1,616
Provision (Benefit) for Income Taxes		(1,117	)		58		(240	)		—			(1,299	)
Capital Expenditures		3,749			300		—			—			4,049

(a)	The provision for income taxes in the Midstream segment in 2017 is presented before consolidating its operations with other U.S. activities of the Company and prior to evaluating realizability of net U.S. deferred taxes. An offsetting impact is presented in the E&P segment.

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)
2017
Operating revenues	$	3,692		$	629		$	675		$	470		$	—		$	5,466
Net income (loss) from continuing operations attributable to Hess Corporation		(2,433	)		(1,383	)		259			(54	)		(463	)		(4,074	)
Depreciation, depletion and amortization		1,942			381			263			273			24			2,883
Impairment		1,700			2,503			—			—			—			4,203
Provision (benefit) for income taxes		—			(1,999	)		197			(9	)		(26	)		(1,837	)
Identifiable assets		13,640			1,024			428			3,850			4,170			23,112
Property, plant and equipment (net)		11,894			946			365			2,964			23			16,192
Capital expenditures		1,387			141			30			415			—			1,973
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	)
Capital expenditures		2,727			297			160			865			—			4,049

(a)	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

Financial Risk Management Activities (Tables)

12 Months Ended

Dec. 31, 2017

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:

	2017		2016
	(In millions)
Commodity - crude oil (millions of barrels)		42		—
Foreign exchange	$	52	$	785
Interest rate swaps	$	450	$	350

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:

	Assets			Liabilities
	(In millions)
December 31, 2017
Derivative Contracts Designated as Hedging Instruments
Commodity - Accounts payable	$	—		$	(7	)
Interest rate - Other assets (noncurrent) and Accounts payable		—			(4	)
Total derivative contracts designated as hedging instruments		—			(11	)
Derivative Contracts Not Designated as Hedging Instruments
Commodity - Accounts payable		—			(2	)
Foreign exchange		1			—
Total derivative contracts not designated as hedging instruments		1			(2	)
Gross fair value of derivative contracts		1			(13	)
Net Fair Value of Derivative Contracts	$	1		$	(13	)

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 - Accounts receivable and Accrued liabilities		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		$	—

Nature of Operations, Basis of Presentation and Summary of Accounting Policies - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Apr. 30, 2017	Dec. 31, 2017	Jan. 01, 2017	Dec. 31, 2016
Summary Of Significant Accounting Policies [Line Items]
Deferred income taxes in non-current assets		$ 21,000,000		$ 59,000,000
Retained earnings		5,597,000,000		10,147,000,000
Capital in excess of par value		5,824,000,000		5,773,000,000
Cumulative effect adjustment to Retained earnings				$ (37,000,000)
Reserve for estimated remediation liabilities		$ 80,000,000
Accounting Standards Update (ASU) 2016-16 \| Restatement Adjustment
Summary Of Significant Accounting Policies [Line Items]
Deferred income taxes in non-current assets			$ (37,000,000)
Retained earnings			(37,000,000)
Accounting Standards Update (ASU) 2016-09 \| Restatement Adjustment
Summary Of Significant Accounting Policies [Line Items]
Retained earnings			(2,000,000)
Capital in excess of par value			2,000,000
Cumulative effect adjustment to Retained earnings			$ 0
Hess Corporation
Summary Of Significant Accounting Policies [Line Items]
Variable interest in Hess Infrastructure Partners LP (HIP)	50.00%	50.00%

Dispositions - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($) a
Disposition Of Businesses [Line Items]
Proceeds from asset sales	$ 3,296	$ 140	$ 50
Gains (losses) on asset sales, net	(86)	23	51
Loss included recognition earnings for cumulative translation adjustments	900	0	0
Interest in Algeria
Disposition Of Businesses [Line Items]
Gains (losses) on asset sales, net			(21)
Gain (loss) on asset sale, after-tax			(21)
Miscellaneous Non-core Assets
Disposition Of Businesses [Line Items]
Proceeds from asset sales	194	100
Gains (losses) on asset sales, net	12	23
Gain (loss) on asset sale, after-tax	12	$ 14
Permian Basin
Disposition Of Businesses [Line Items]
Proceeds from asset sales	597
Gains (losses) on asset sales, net	273
Gain (loss) on asset sale, after-tax	280
Permian Basin \| Exploration and Production
Disposition Of Businesses [Line Items]
Gain (loss) on asset sale, after-tax	314
Permian Basin \| Midstream
Disposition Of Businesses [Line Items]
Gain (loss) on asset sale, after-tax	(34)
Equatorial Guinea
Disposition Of Businesses [Line Items]
Proceeds from asset sales	449
Gains (losses) on asset sales, net	486
Gain (loss) on asset sale, after-tax	486
Offshore Norway
Disposition Of Businesses [Line Items]
Proceeds from asset sales	2,056
Gains (losses) on asset sales, net	(857)
Gain (loss) on asset sale, after-tax	$ (857)
Net Acres in Utica Dry Gas Area of Utica Shale
Disposition Of Businesses [Line Items]
Gains (losses) on asset sales, net			49
Gain (loss) on asset sale, after-tax			$ 31
Net acres of Utica dry gas acreage sold \| a			13,000
Sales price of Utica dry gas acreage sold			$ 120
Joint Venture Interest in Bayonne Energy Center
Disposition Of Businesses [Line Items]
Proceeds from asset sales			20
Gains (losses) on asset sales, net			20
Gain (loss) on asset sale, after-tax			$ 13

Dispositions - Schedule of Pre-tax Income (Loss) Associated with Interests Excluding Financial Statement Impacts Resulting from Asset Sales (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	$ (5,778)	$ (3,854)	$ (4,258)
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	14	(290)	(299)
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Equatorial Guinea
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	69	(95)	(23)
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Norway
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	$ (55)	$ (195)	$ (276)

Dispositions - Schedule of Pre-tax Income (Loss) Associated with Interests Excluding Financial Statement Impacts Resulting from Asset Sales (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended		9 Months Ended	12 Months Ended
	Dec. 31, 2017	Nov. 30, 2017	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disposition Of Businesses [Line Items]
Impairment				$ 4,203	$ 67	$ 1,616
Norway
Disposition Of Businesses [Line Items]
Impairment			$ 2,503
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Equatorial Guinea
Disposition Of Businesses [Line Items]
Gains (loss) on sales of assets		$ 486
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Norway
Disposition Of Businesses [Line Items]
Gains (loss) on sales of assets	$ (857)
Impairment				$ 2,503

Impairment - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Impairments [Line Items]
Impairment charge, pre-tax			$ 4,203	$ 67	$ 1,616
Fair value of estimated impairment charges determined using internal projected discounted cash flows	$ 1,100
Goodwill impairment charge, pre-tax					1,483
Goodwill impairment charge, after-tax					1,483
Norway
Impairments [Line Items]
Impairment charge, pre-tax		$ 2,503
Impairment charge, after-tax		$ 550
Midstream
Impairments [Line Items]
Impairment charge, pre-tax				67
Impairment charge, after-tax and noncontrolling interest				$ 21
Legacy conventional North Dakota Assets
Impairments [Line Items]
Impairment charge, pre-tax					133
Impairment charge, after-tax					$ 83
Stampede Field
Impairments [Line Items]
Impairment charge, pre-tax	1,095
Percentage of working interest prior to unitizing			100.00%
Impairment charge, after-tax	1,095
Tubular Bells Field
Impairments [Line Items]
Impairment charge, pre-tax	605
Impairment charge, after-tax	$ 605

Inventories - Inventories (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 59	$ 77
Materials and supplies	173	246
Total Inventories	$ 232	$ 323

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

Dec. 31, 2017

Dec. 31, 2016

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

$ 32,504

$ 46,907

16,312

23,312

Property, plant and equipment — net

16,192

23,595

^[1]

Exploration and Production

Wells, equipment and related facilities

Unproved properties

520

710

Proved properties

3,162

4,249

25,550

38,250

29,232

43,209

Midstream

3,219

3,598

Corporate and Other

$ 53

$ 100

[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) Well	Dec. 31, 2016 USD ($) Well	Dec. 31, 2015 USD ($) Well
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 597	$ 1,415	$ 1,416
Additions to capitalized exploratory well costs pending the determination of proved reserves	116	79	424
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(165)	0	(72)
Capitalized exploratory well costs charged to expense	(268)	(897)	(356)
Dispositions and other	24	0	3
Ending balance	$ 304	$ 597	$ 1,415
Number of Wells at December 31 \| Well	12	17	35

Property, Plant and Equipment - Capitalized Exploratory Well Costs - Additional Information (Detail) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017 USD ($)	Jun. 30, 2016 USD ($) Well	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Capitalized Exploratory Well Costs [Line Items]
Charge to write-off previously capitalized exploratory wells			$ 268	$ 897	$ 356
Exploratory dry hole costs which were incurred and subsequently expensed				$ 167	$ 54
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 170		$ 170
Hess-operated Equus Natural Gas Project, Australia
Capitalized Exploratory Well Costs [Line Items]
Charge to write-off previously capitalized exploratory wells		$ 830
Gulf Of Mexico
Capitalized Exploratory Well Costs [Line Items]
Number of wells expensed during the period \| Well		2
Northern Portion of Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	28.00%		28.00%
Capitalized well costs percentage	70.00%		70.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	50.00%		50.00%
Capitalized well costs percentage	20.00%		20.00%
Ghana
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	50.00%		50.00%
Charge to write-off previously capitalized exploratory wells	$ 268		$ 268

Property, Plant and Equipment - Exploratory Drilling Costs Capitalized (Detail) $ in Millions	Dec. 31, 2017 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	$ 170
Year 2016
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	0
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	166
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	0
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	$ 4

Goodwill - Changes in Carrying Amount of Goodwill (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($)
Goodwill [Line Items]
Balance at December 31	$ 375
Dispositions	(15)
Balance at December 31	360
Exploration and Production
Goodwill [Line Items]
Balance at December 31	0
Dispositions	0
Balance at December 31	0
Midstream
Goodwill [Line Items]
Balance at December 31	375
Dispositions	(15)
Balance at December 31	$ 360

Hess Infrastructure Partners LP - Additional Information (Detail) - USD ($)
$ in Millions

1 Months Ended

12 Months Ended

48 Months Ended

Jul. 01, 2015

Apr. 30, 2017

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2017

Dec. 31, 2014

Percentage interest sold of Hess Infrastructure Partners (HIP)

50.00%

Proceeds from sale of interest in Hess Infrastructure Partners (HIP)

$ 2,628

$ 0

$ 2,628

Term of tariff agreements between E&P operating segment & Midstream entities

10 years

Additional renewal period of tariff agreements by Midstream

10 years

Noncontrolling interest, ownership percentage

50.00%

After tax gain from sale of equity interest

2,061

Cash and cash equivalents

$ 4,847

2,732

2,716

$ 4,847

$ 2,444

Hess Infrastructure Partners LP (HIP)

16,192

23,595

^[1]

16,192

Cash and cash equivalents

356

HIP's liabilities on a nonrecourse to Hess Corporation

$ 2,520

$ 2,528

$ 2,520

liabilities totaling $1,065 million (2016: $841 million)

Capital in Excess of Par Value

After tax gain from sale of equity interest

763

Noncontrolling Interests

After tax gain from sale of equity interest

$ 1,298

Hess Corporation

Ownership percentage in Hess Infrastructure Partners LP (HIP)

50.00%

[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

Hess Midstream Partners LP - Initial Public Offering - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Apr. 30, 2017	Dec. 31, 2017
Limited Partners' Capital Account [Line Items]
Noncontrolling interest, ownership percentage	50.00%	50.00%
Public Unit Holders
Limited Partners' Capital Account [Line Items]
Percentage of ownership interest in Partnership	30.50%	30.50%
Hess Infrastructure Partners LP (HIP)
Limited Partners' Capital Account [Line Items]
Partnership controlling interest in operating companies, percentage	80.00%	80.00%
Percentage of economic interest in the Partnership plus incentive distribution rights of general partner	2.00%	2.00%
Global Infrastructure Partners (GIP)
Limited Partners' Capital Account [Line Items]
Initial public offering partial proceeds distribution percentage	50.00%	50.00%
Percentage of indirect ownership interest		a 50% indirect ownership interest through HIP
Hess Corporation
Limited Partners' Capital Account [Line Items]
Initial public offering partial proceeds distribution percentage	50.00%	50.00%
Ownership percentage in Hess Infrastructure Partners LP (HIP)	50.00%	50.00%
Percentage of indirect ownership interest		a 50% indirect ownership interest through HIP
Hess Midstream Partners LP
Limited Partners' Capital Account [Line Items]
Initial public offering common units sold	16,997,000
Initial public offering sale price per unit	$ 23
Net proceeds from initial public offering	$ 365.5
Of this amount distributed 50/50 to Hess Corporation and GIP	$ 350.0
Partnership controlling interest in operating companies, percentage	20.00%	20.00%
Hess Midstream Partners LP \| Global Infrastructure Partners (GIP)
Limited Partners' Capital Account [Line Items]
Percentage of ownership interest in Partnership	33.75%	33.75%
Hess Midstream Partners LP \| Hess Corporation
Limited Partners' Capital Account [Line Items]
Percentage of ownership interest in Partnership	33.75%	33.75%

Asset Retirement Obligations - Changes to Asset Retirement Obligations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 2,128	$ 2,383
Liabilities incurred	62	42
Liabilities settled or disposed of	(1,464)	(196)
Accretion expense	97	117
Revisions of estimated liabilities	(54)	(230)
Foreign currency translation	32	12
Asset retirement obligations at end of period	801	2,128
Less: Current Obligations	48	216
Long-term Obligations at end of period	$ 753	$ 1,912

Asset Retirement Obligations - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Fair value of sinking fund deposits legally restricted for purposes of settling asset retirement obligations	$ 118	$ 102

Debt - Components of Debt (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Total debt	$ 6,977	$ 6,806
Less: Current maturities of long-term debt	580	112
Total Long-Term Debt	6,397	6,694
Midstream
Debt Instrument [Line Items]
Total debt	980	733
Midstream \| Hess Infrastructure Partners
Debt Instrument [Line Items]
Term loan A facility	195	580
Revolving credit facility	0	153
Midstream \| Hess Midstream Partners LP
Debt Instrument [Line Items]
Revolving credit facility	0	0
Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	5,879	5,874
Financing obligations associated with floating production system	118	192
Fair value adjustments - interest rate hedging	0	7
Total debt	5,997	6,073
8.1% Due 2019 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	349	349
Less: Current maturities of long-term debt	349
3.5% Due 2024 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	297	297
4.3% due 2027 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	991	989
7.9% Due 2029 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	500	499
7.3% Due 2031 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	679	679
7.1% Due 2033 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	596	596
6.0% Due 2040 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	740	740
5.6% Due 2041 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	1,234	1,232
5.8% Due 2047 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	493	493
5.6% Due 2026 \| Midstream \| Hess Infrastructure Partners
Debt Instrument [Line Items]
Fixed-rate public notes	$ 785	$ 0

Debt - Components of Debt (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Fair value of total debt	$ 7,718	$ 7,548
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
5.6% Due 2026
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2026

Debt - Maturity Profile of Total Debt (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
2018	$ 580
2019	51
2020	15
2021	16
2022	151
Thereafter	6,164
Total debt	6,977	$ 6,806
Midstream
Debt Instrument [Line Items]
2018	2
2019	11
2020	15
2021	16
2022	151
Thereafter	785
Total debt	980	733
Hess Corporation
Debt Instrument [Line Items]
2018	578
2019	40
2020	0
2021	0
2022	0
Thereafter	5,379
Total debt	$ 5,997	$ 6,073

Debt - Additional Information (Detail) - USD ($)		1 Months Ended				12 Months Ended
Debt - Additional Information (Detail) - USD ($)	Feb. 15, 2018	Dec. 31, 2017	Nov. 30, 2017	Oct. 31, 2016	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Fixed-rate notes, gross principal amount		$ 5,938,000,000				$ 5,938,000,000	$ 5,938,000,000
Weighted average interest rate		6.00%				6.00%	6.00%
Additional secured debt allowed to be borrowed		$ 3,352,000,000				$ 3,352,000,000
Capitalized interest						86,000,000	$ 61,000,000	$ 45,000,000
Net proceeds from senior notes issued					$ 1,380,000,000		1,380,000,000
Loss on debt extinguishment						0	148,000,000	$ 0
Revolving credit facility period extended		1 year
Commitment during extension period		$ 3,700,000,000				3,700,000,000
Letters of credit – Issued		246,000,000				246,000,000	188,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility - Capacity		$ 4,000,000,000				$ 4,000,000,000
Revolving credit facility extended expiration date		Jan. 31, 2021
Revolving credit facility – Interest rate						1.30% 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 60% of the Corporation’s total capitalization, defined as total debt plus stockholders’ equity.
Debt instrument covenant, percentage		60.00%
Revolving credit facility - Outstanding amount		$ 0				$ 0
Letters of credit – Issued		0				0
Revolving Credit Facility \| Hess Midstream Partners LP
Debt Instrument [Line Items]
Revolving credit facility - Capacity		$ 300,000,000				$ 300,000,000
Revolving credit facility - Term						4 years
Revolving Credit Facility \| London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		1.30%
Midstream
Debt Instrument [Line Items]
Revolving credit facility - Capacity			$ 600,000,000				400,000,000
Revolving credit facility extended expiration date			Nov. 30, 2022
Term Loan A facility - Term			5 years
Borrowings - Term Loan A			$ 200,000,000
Revolving credit facility - Term			5 years
Leverage ratio - Maximum			500.00%
Interest coverage ratio - Minimum						2.25 to 1.0
Secured leverage ratio - Maximum			375.00%
Midstream \| Hess Midstream Partners LP
Debt Instrument [Line Items]
Revolving credit facility - Outstanding amount		$ 0				$ 0	0
Midstream \| London Interbank Offered Rate (LIBOR) \| Minimum
Debt Instrument [Line Items]
Interest rate			1.55%
Midstream \| London Interbank Offered Rate (LIBOR) \| Maximum
Debt Instrument [Line Items]
Interest rate			2.50%
Midstream \| Revolving Credit Facility \| London Interbank Offered Rate (LIBOR) \| Minimum
Debt Instrument [Line Items]
Interest rate			1.275%
Midstream \| Revolving Credit Facility \| London Interbank Offered Rate (LIBOR) \| Maximum
Debt Instrument [Line Items]
Interest rate			2.00%
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%
8.1% Due 2019
Debt Instrument [Line Items]
Debt instrument coupon rate					8.125%		8.125%
Notes repurchase principal amount					$ 650,000,000		$ 650,000,000
Debt instrument maturity year					2019		2019
8.1% Due 2019 \| Subsequent Event \| Debt Hess Corporation
Debt Instrument [Line Items]
Debt instrument coupon rate	8.125%
Notes repurchase principal amount	$ 350,000,000
Debt instrument maturity year	2019
7.9% 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
Senior Notes Due in November 2026 \| Midstream
Debt Instrument [Line Items]
Unsecured debt issued			$ 800,000,000
Debt instrument maturity year			2026-02
Debt instrument coupon rate			5.625%

Debt - Other Outstanding Letters of Credit (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 246	$ 188
Committed Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	29	1
Uncommitted Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 217	$ 187

Debt - Other Outstanding Letters of Credit (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 246	$ 188
Letters of Credit Outstanding - Recorded in Balance Sheet
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 215	$ 161
Committed and Uncommitted Lines
Line Of Credit Facility [Line Items]
Maturity year	2018

Share-based Compensation - Additional Information (Detail) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) $ / shares shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of authorized common stock shares under LTIP, as amended \| shares	51,500,000
Number of shares under LTIP, as amended, available for issuance of restricted common shares, performance share units and stock options \| shares	20,800,000
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 2018	$ 65.0
Unearned compensation expense, before income taxes due 2019	34.0
Unearned compensation expense, before income taxes due 2020	$ 5.0
Outstanding stock options \| shares	6,482,000
Number of stock options, exercisable \| shares	5,220,000
Weighted average remaining contractual life for options, outstanding	3 years 7 months 6 days
Weighted average remaining contractual life for options, exercisable	2 years 3 months 18 days
Aggregated intrinsic value	$ 2.2
Aggregated intrinsic value for exercisable options	$ 0.8
Weighted average exercise price for options, exercisable \| $ / shares	$ 70.65
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period from date of grant, in years	3 years

Share-based Compensation - Share-based Compensation Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 86	$ 73	$ 97
Income tax benefit on share-based compensation expense	1	28	36
Restricted Stock
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	56	45	67
Stock Options
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	9	7	5
Performance Share Units
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 21	$ 21	$ 25

Share-based Compensation - Summary of Stock-based Compensation Activity (Detail) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Exercised	(200)	(200)	(200)
Options - Outstanding at end of period	6,482
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	$ 61.93
Weighted average fair value on date of grant - Granted	50.98
Weighted average fair value on date of grant - Vested	81.06
Weighted average fair value on date of grant - Forfeited	56.72
Weighted average fair value on date of grant - Outstanding at end of period	$ 54.04	$ 61.93
Awards - Outstanding at beginning of period	3,101
Awards - Granted	1,216
Awards - Vested	(729)
Awards - Forfeited	(386)
Awards - Outstanding at end of period	3,202	3,101
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	$ 67.15
Weighted average exercise price per share - Granted	51.03
Weighted average exercise price per share - Exercised	52.75
Weighted average exercise price per share - Forfeited	56.66
Weighted average exercise price per share - Outstanding at end of period	$ 66.84	$ 67.15
Options - Outstanding at beginning of period	6,592
Options - Granted	662
Options - Exercised	(152)
Options - Forfeited	(620)
Options - Outstanding at end of period	6,482	6,592
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	$ 69.68
Weighted average fair value on date of grant - Granted	52.86
Weighted average fair value on date of grant - Vested	90.37
Weighted average fair value on date of grant - Forfeited	61.23
Weighted average fair value on date of grant - Outstanding at end of period	$ 58.78	$ 69.68
Awards - Outstanding at beginning of period	1,015
Awards - Granted	439
Awards - Vested	(265)
Awards - Forfeited	(43)
Awards - Outstanding at end of period	1,146	1,015
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	2.17%	1.47%	1.77%
Stock price volatility	0.333%	0.326%	0.312%
Dividend yield	1.96%	2.26%	1.34%
Expected life in years	6 years	6 years	6 years
Weighted average fair value per option granted	$ 14.51	$ 11.33	$ 21.00

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards (Detail) - Performance Share Units - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	1.55%	0.96%	1.02%
Stock price volatility	0.387%	0.329%	0.27%
Contractual term in years	3 years	3 years	3 years
Grant date price of Hess common stock	$ 51.03	$ 44.31	$ 74.49

Retirement Plans - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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
Budgeted contributions to funded pension plans for next year		$ 44
Expense for defined contribution plans		$ 22	$ 25	$ 28
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]
Service cost	$ 55
Interest cost	90
Amortization of unrecognized net actuarial losses	50
Expected return on plan assets	195
Expected decrease in service cost and interest cost	$ 12
Funded and Unfunded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		$ 2,679	2,471
Service cost		49	60	67
Interest cost		102	107	102
Amortization of unrecognized net actuarial losses		58	60	75
Expected return on plan assets		168	166	$ 168
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		190	203
Service cost		13	16
Interest cost		$ 9	$ 9

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Change In Fair Value of Plan Assets
Beginning balance	$ 2,284
Ending balance	2,732	$ 2,284
Funded Pension Plans
Change In Benefit Obligation
Beginning balance	2,560	2,321
Service cost	36	44
Interest cost	93	98
Actuarial loss (gain)	138	162
Benefit payments	(113)	(132)
Plan curtailments	(3)	(2)
Special termination benefits	0	1
Assumption of HOVENSA pension plan	0	151
Foreign currency exchange rate changes	54	(83)
Ending balance	2,765	2,560	$ 2,321
Change In Fair Value of Plan Assets
Beginning balance	2,284	2,206
Actual return on plan assets	351	153
Employer contributions	158	26
Benefit payments	(113)	(132)
Assumption of HOVENSA pension plan	0	126
Foreign currency exchange rate changes	52	(95)
Ending balance	2,732	2,284	2,206
Funded Status (Plan assets greater (less) than benefit obligations) at December 31	(33)	(276)
Unrecognized Net Actuarial (Gains) Losses	789	895
Unfunded Pension Plan
Change In Benefit Obligation
Beginning balance	256	259
Service cost	13	16
Interest cost	9	9
Actuarial loss (gain)	10	(5)
Benefit payments	(39)	(23)
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	249	256	259
Change In Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	39	23
Benefit payments	(39)	(23)
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	(249)	(256)
Unrecognized Net Actuarial (Gains) Losses	84	93
Postretirement Medical Plan
Change In Benefit Obligation
Beginning balance	84	98
Service cost	4	4	4
Interest cost	3	3	3
Actuarial loss (gain)	3	(13)
Benefit payments	(7)	(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	87	84	98
Change In Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	7	8
Benefit payments	(7)	(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	(87)	(84)
Unrecognized Net Actuarial (Gains) Losses	$ (10)	$ (13)

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, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Lump-sum settlement payment included in Benefit payments	$ 57	$ 65
Change in Discount Rate
Defined Benefit Plan Disclosure [Line Items]
Actuarial loss (gain) resulted from a change	$ 170	$ 175

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	$ (33)	$ (276)
Accumulated other comprehensive loss, pre-tax	789	895
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	(249)	(256)
Accumulated other comprehensive loss, pre-tax	84	93
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Pension asset / (accrued benefit liability)	(87)	(84)
Accumulated other comprehensive loss, pre-tax	$ (10)	$ (13)

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Compensation And Retirement Disclosure [Abstract]
Accumulated other comprehensive (gain) loss related to retirement plans, after-tax	$ 548	$ 660

Retirement Plans - Components of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 49	$ 60	$ 67
Interest cost	102	107	102
Expected return on plan assets	(168)	(166)	(168)
Amortization of unrecognized net actuarial losses	58	60	75
Settlement loss	19	0	17
Special termination benefit recognized	0	1	1
Net Periodic Benefit Cost	60	62	94
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Pension Plans
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.30%	3.70%	4.10%
Rate of compensation increase	4.50%	4.60%	4.50%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost for the Years Ended December 31
Discount rate	3.70%	4.10%	3.80%
Expected return on plan assets	7.30%	7.40%	7.50%
Rate of compensation increase	4.60%	4.50%	5.00%
Postretirement Medical Plan
Weighted Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.20%	3.50%	3.50%
Initial health care trend rate	7.30%	7.70%	6.70%
Ultimate trend rate	4.50%	4.50%	4.50%
Year in which ultimate trend rate is reached	2038	2038	2038

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, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	$ 389	$ 393
Actual return on plan assets	32	5
Purchases, sales or other settlements	2	(9)
Net transfers in (out) of Level 3	(1)	0
Ending balance	422	389
Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	2	3
Actual return on plan assets	0	0
Purchases, sales or other settlements	0	(1)
Net transfers in (out) of Level 3	(1)	0
Ending balance	1	2
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	209	216
Actual return on plan assets	3	(7)
Purchases, sales or other settlements	(25)	0
Net transfers in (out) of Level 3	0	0
Ending balance	187	209
Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	126	122
Actual return on plan assets	18	5
Purchases, sales or other settlements	(4)	(1)
Net transfers in (out) of Level 3	0	0
Ending balance	140	126
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	52	52
Actual return on plan assets	11	7
Purchases, sales or other settlements	31	(7)
Net transfers in (out) of Level 3	0	0
Ending balance	$ 94	$ 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]
2018	$ 127
2019	142
2020	142
2021	141
2022	145
Years 2023 to 2027	$ 748

Exit and Disposal Costs - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restructuring And Related Activities [Abstract]
Severance expense	$ 18	$ 55	$ 13
Accrued severance costs paid	48	52	57
Other facility and exit related costs	14		15
Other facility and exit related costs paid	3	2	$ 21
Accrued severance costs	6	36
Restructuring Reserve	$ 28	$ 17
Expected period for all payments for severance cost	all severance costs are expected to be paid in 2018

Income Taxes - Components of Income Tax Provision (Benefit) for Continuing Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
United States - Federal, Current income tax expense (benefit)	$ (23)	$ (27)	$ (7)
United States - Federal, Deferred income taxes and other accruals expense (benefit)	(6)	1,948	(995)
United States - State, Current & Deferred income taxes and other accruals expense (benefit)	0	23	(61)
United States, Current & Deferred income taxes and other accruals expense (benefit)	(29)	1,944	(1,063)
Foreign, Current income tax expense (benefit)	179	36	4
Foreign, Deferred income taxes and other accruals expense (benefit)	(1,987)	235	(231)
Foreign, Current & Deferred income taxes and other accruals expense (benefit)	(1,808)	271	(227)
Provision (benefit) for income taxes - before adjustments due to income tax law changes	(1,837)	2,215	(1,290)
Adjustment of deferred taxes for foreign income tax law changes	0	7	(9)
Total Provision (Benefit) For Income Taxes	$ (1,837)	$ 2,222	$ (1,299)

Income Taxes - Components of Income Tax Provision (Benefit) for Continuing Operations (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
United States, Denmark and Malaysia
Income Tax Expense Benefit Continuing Operations [Line Items]
Valuation allowance against net deferred tax assets	$ 3,749

Income Taxes - Income (Loss) From Continuing Operations Before Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income (Loss) From Continuing Operations Before Income Taxes - United States	$ (2,784)	$ (2,431)	$ (2,728)
Income (Loss) From Continuing Operations Before Income Taxes - Foreign	(2,994)	(1,423)	(1,530)
Income (Loss) from Continuing Operations Before Income Taxes	$ (5,778)	$ (3,854)	$ (4,258)

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Deferred Tax Liabilities
Property, plant and equipment and investments	$ (629)	$ (3,810)
Other	(24)	(255)
Total Deferred Tax Liabilities	(653)	(4,065)
Deferred Tax Assets
Net operating loss carryforwards	4,029	5,767
Tax credit carryforwards	138	164
Property, plant and equipment and investments	746	834
Accrued compensation, deferred credits and other liabilities	283	526
Asset retirement obligations	212	1,077
Other	36	62
Total Deferred Tax Assets	5,444	8,430
Valuation allowances	(5,199)	(5,450)
Total deferred tax assets, net of valuation allowances	245	2,980
Net Deferred Tax Assets (Liabilities)	$ (408)	$ (1,085)

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Examination [Line Items]
Gross deferred tax asset related to net operating loss carryforwards		$ 4,029,000,000	$ 5,767,000,000
Gross deferred tax asset related to foreign net operating loss carryforwards		1,386,000,000
Gross deferred tax asset related to net U.S. federal operating loss carryforwards		$ 2,180,000,000
Year in which majority portion of U.S. federal net operating loss carryforwards begin to expire		2034
Gross deferred tax asset related to net operating loss carryforwards for various U.S. states		$ 463,000,000
Deferred tax asset related to foreign net operating loss carryforwards, net of valuation allowance		9,000,000
Alternative minimum tax credit carryforwards		53,000,000
Other business credit carryforwards		15,000,000
Deferred tax asset related to business credit carryforwards, net of valuation allowance		4,000,000
Foreign tax credit carryforwards - Before valuation allowance		$ 70,000,000
Year in which foreign tax credit carryforwards begin to expire		2018
Valuation allowance against net deferred tax assets		$ 5,199,000,000	$ 5,450,000,000
Period of cumulative loss incurred		3 years
Tax accrued on deemed repatriation of unremitted earnings of foreign subsidiaries		$ 0
Federal corporate tax rate		35.00%	35.00%	35.00%
Refundable alternative minimum tax credit if not offset by regular tax liability		$ 4,000,000
Increase to net deferred tax asset and benefit to deferred tax expense due to change in tax law		4,000,000
Unrecognized tax benefits that would impact effective income tax rate		30,000,000	$ 233,000,000
Accrued interest and penalties		23,000,000	$ 29,000,000
Minimum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible		58,000,000
Maximum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible		139,000,000
Tax Reform - Tax Rate
Income Tax Examination [Line Items]
Decrease in net deferred tax asset due to tax rate change		(1,476,000,000)
Tax Reform - Territorial Regime
Income Tax Examination [Line Items]
Decrease in net deferred tax asset due to tax rate change		$ 110,000,000
Scenario Forecast
Income Tax Examination [Line Items]
Federal corporate tax rate	21.00%
Foreign
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date		Jan. 01, 2024
U.S. Federal
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date		Jan. 01, 2028
U.S. State
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date		Jan. 01, 2018

Income Taxes - Deferred Tax Assets and Liabilities, Net (Detail) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Deferred income taxes	$ 21	$ 59
Deferred income taxes (long-term liability)	(429)	(1,144)
Net Deferred Tax Assets (Liabilities)	$ (408)	$ (1,085)

Income Taxes - Effective Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
U.S. statutory rate	35.00%	35.00%	35.00%
Effect of foreign operations	17.40%	4.60%	5.90%
State income taxes, net of Federal income tax	0.00%	1.90%	0.90%
Change in enacted tax laws	(23.60%)	(0.20%)	0.20%
Valuation allowance adjustment with tax law change	23.60%	0.00%	0.00%
Rate differential on U.S. impairment	(4.10%)	0.00%	0.00%
Gains on asset sales, net	(2.20%)	0.00%	(0.20%)
Impairment	0.00%	(2.10%)	(12.20%)
Valuation allowance on current year operations	(14.90%)	0.00%	0.00%
Valuation allowance against previously benefitted deferred tax assets	0.10%	(97.30%)	(3.10%)
Benefit of legal entity restructuring	0.00%	0.00%	3.50%
Other	0.50%	0.40%	0.50%
Total	31.80%	(57.70%)	30.50%

Income Taxes - Effective Income Tax Rate Reconciliation (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Line Items]
Federal corporate tax rate		35.00%	35.00%	35.00%
Decrease in net deferred tax asset due to tax reform		$ 1,366
Scenario Forecast
Income Taxes [Line Items]
Federal corporate tax rate	21.00%

Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Balance at January 1	$ 424	$ 604	$ 603
Additions based on tax positions taken in the current year	14	19	19
Additions based on tax positions of prior years	4	113	29
Reductions based on tax positions of prior years	(147)	(274)	(31)
Reductions due to settlements with taxing authorities	(85)	(27)	(12)
Reductions due to lapses in statutes of limitation	(5)	(11)	(4)
Balance at December 31	$ 205	$ 424	$ 604

Common and Preferred Stock Issuance - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 29, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class Of Stock [Line Items]
Shares of stock issued		0	28,800,000	0
Cumulative mandatory convertible series		8.00%	8.00%
Preferred stock, par value		$ 1.00	$ 1.00
Preferred stock, liquidation preference per share		$ 1,000	$ 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

Outstanding and Weighted Average Common Shares - Changes in Outstanding Common Shares (Detail) - shares shares in Thousands	12 Months Ended			58 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2017
Earnings Per Share [Abstract]
Balance at January 1	316,500	286,000	285,800
Shares issued	0	28,800	0
Activity related to restricted stock awards, net	800	1,100	800
Stock options exercised	200	200	200
PSU vested	200	400	600
Shares repurchased	(2,630)	0	(1,450)	(66,740)
Balance at December 31	315,100	316,500	286,000	315,100

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Income (loss) from continuing operations, net of income taxes	$ (3,941)	$ (6,076)	$ (2,959)
Less: Net income (loss) attributable to noncontrolling interests	133	56	49
Net income (loss) from continuing operations attributable to Hess Corporation	(4,074)	(6,132)	(3,008)
Less: Preferred stock dividends	46	41	0
Net income (loss) from continuing operations attributable to Hess Corporation Common Stockholders	(4,120)	(6,173)	(3,008)
Income (loss) from discontinued operations, net of income taxes	0	0	(48)
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (4,120)	$ (6,173)	$ (3,056)
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Basic	314.1	309.9	283.6
Diluted	314.1	309.9	283.6
Net Income (Loss) Attributable to Hess Corporation per Common Share – Basic:
Continuing operations	$ (13.12)	$ (19.92)	$ (10.61)
Discontinued operations	0	0	(0.17)
Net Income (Loss) Per Common Share	(13.12)	(19.92)	(10.78)
Net Income (Loss) Attributable to Hess Corporation per Common Share – Diluted:
Continuing operations	(13.12)	(19.92)	(10.61)
Discontinued operations	0	0	(0.17)
Net Income (Loss) Per Common Share	$ (13.12)	$ (19.92)	$ (10.78)
Restricted Common Stock
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Stock Options
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Mandatory Convertible Preferred Stock
Weighted Average Number of Common 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, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Common Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	3.3	3.3	2.9
Stock Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	6.4	6.9	6.9
Performance Share Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	0.6	0.9	1.0
Common Shares from Conversion of Preferred Stocks
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	12.8	11.2	0.0

Outstanding and Weighted Average Common Shares - Additional Information (Detail) - $ / shares	3 Months Ended												12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	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, 2017	Dec. 31, 2016	Dec. 31, 2015
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	12 Months Ended				58 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2017	May 31, 2014	Mar. 31, 2013
Equity Class Of Treasury Stock [Line Items]
Repurchase of outstanding common stock						$ 6,500	$ 4,000
Additional amount of common stock that may be repurchased		$ 1,030			$ 1,030
Common stock to be repurchased		$ 120	$ 0	$ 91	$ 5,471
Scenario Forecast
Equity Class Of Treasury Stock [Line Items]
Common stock to be repurchased	$ 380

Share Repurchase Plan - Schedule of Share Repurchases Under Share Repurchase Plan - (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended			58 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2017
Equity [Abstract]
Total cost of shares repurchased	$ 120	$ 0	$ 91	$ 5,471
Total number of shares repurchased	2,630	0	1,450	66,740
Average cost per share (including transaction fees)	$ 45.67	$ 0	$ 62.76	$ 81.96

Supplementary Cash Flow Information (Detail) - USD ($) $ in Millions		12 Months Ended
	Jul. 01, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows From Operating Activities
Interest paid		$ (314)	$ (338)	$ (331)
Net income taxes (paid) refunded		(210)	132	(140)
Cash Flows From Investing Activities
Capital expenditures incurred - E&P		(1,852)	(1,638)	(3,749)
Increase (decrease) in related liabilities - E&P		64	(336)	(203)
Additions to property, plant and equipment - E&P		(1,788)	(1,974)	(3,952)
Capital expenditures incurred - Midstream		(121)	(283)	(300)
Increase (decrease) in related liabilities - Midstream		(28)	6	(69)
Additions to property, plant and equipment - Midstream		(149)	(277)	(369)
Cash Flows From Financing Activities
Proceeds from sale of interest in Hess Infrastructure Partners (HIP)	$ 2,628	0	0	2,628
Distributions to noncontrolling interests		(243)	(23)	(332)
Noncontrolling interests, net related to Continuing operations		$ (243)	$ (23)	$ 2,296

Leased Assets - Future Minimum Rental Payments (Detail) $ in Millions	Dec. 31, 2017 USD ($)
Leases [Abstract]
2018	$ 387
2019	376
2020	130
2021	71
2022	70
Remaining years	276
Total Minimum Lease Payments	1,310
Less: Income from subleases	99
Net Minimum Lease Payments	$ 1,211

Leased Assets - Rental Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Leases [Abstract]
Total rental expense	$ 123	$ 106	$ 167
Less: Income from subleases	10	5	10
Net Rental Expense	$ 113	$ 101	$ 157

Guarantees, Contingencies and Commitments - Additional Information (Detail) $ in Millions		1 Months Ended	12 Months Ended
	Mar. 04, 2016 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2017 USD ($) Case
Loss Contingencies [Line Items]
Contingent liabilities under letters of credit outstanding			$ 31.0
Total number of remaining active cases filed \| Case			4
Lower Passaic River
Loss Contingencies [Line Items]
Estimated remediation cost	$ 1,380.0
Gowanus Canal Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost		$ 506.0
Ector Drum, Inc. Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost			$ 3.5

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	$ 1,260
2018	563
2019 and 2020	531
2021 and 2022	166
Thereafter	0
Operating Expenses
Loss Contingencies [Line Items]
Total	412
2018	230
2019 and 2020	121
2021 and 2022	39
Thereafter	22
Transportation and Related Contracts
Loss Contingencies [Line Items]
Total	1,221
2018	210
2019 and 2020	390
2021 and 2022	374
Thereafter	$ 247

Segment Information - Additional Information (Detail)	12 Months Ended
Segment Information - Additional Information (Detail)	Dec. 31, 2017 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, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating Revenues - Third-parties	$ 5,466	$ 4,762	$ 6,636
Intersegment Revenues	0	0	0
Operating Revenues	5,466	4,762	6,636
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	(4,074)	(6,132)	(3,008)
Interest Expense	325	338	341
Depreciation, Depletion and Amortization	2,883	3,244	3,955
Impairment	4,203	67	1,616
Provision (Benefit) for Income Taxes	(1,837)	2,222	(1,299)
Investment in Affiliates	134	146
Identifiable Assets	23,112	28,621
Capital Expenditures	1,973	1,921	4,049
Midstream
Segment Reporting Information [Line Items]
Impairment		67
Operating Segments \| Exploration and Production
Segment Reporting Information [Line Items]
Operating Revenues - Third-parties	5,460	4,755	6,627
Intersegment Revenues	0	0	0
Operating Revenues	5,460	4,755	6,627
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	(3,653)	(4,964)	(2,727)
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	2,736	3,113	3,833
Impairment	4,203	0	1,616
Provision (Benefit) for Income Taxes	(1,842)	1,587	(1,117)
Investment in Affiliates	134	146
Identifiable Assets	15,613	22,856
Capital Expenditures	1,852	1,638	3,749
Operating Segments \| Midstream
Segment Reporting Information [Line Items]
Operating Revenues - Third-parties	6	7	9
Intersegment Revenues	611	562	625
Operating Revenues	617	569	634
Net Income (Loss) from Continuing Operations Attributable to Hess Corporation	42	42	96
Interest Expense	26	19	10
Depreciation, Depletion and Amortization	123	121	107
Impairment	0	67	0
Provision (Benefit) for Income Taxes	31	26	58
Investment in Affiliates	0	0
Identifiable Assets	3,329	3,165
Capital Expenditures	121	283	300
Operating Segments \| 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	(463)	(1,210)	(377)
Interest Expense	299	319	331
Depreciation, Depletion and Amortization	24	10	15
Impairment	0	0	0
Provision (Benefit) for Income Taxes	(26)	609	(240)
Investment in Affiliates	0	0
Identifiable Assets	4,170	2,600
Capital Expenditures	0	0	0
Eliminations
Segment Reporting Information [Line Items]
Operating Revenues - Third-parties	0	0	0
Intersegment Revenues	(611)	(562)	(625)
Operating Revenues	(611)	(562)	(625)
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	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, 2017

Dec. 31, 2016

Dec. 31, 2015

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

$ 5,466

$ 4,762

$ 6,636

(4,074)

(6,132)

(3,008)

2,883

3,244

3,955

4,203

1,616

(1,837)

2,222

(1,299)

23,112

28,621

16,192

23,595

^[1]

Operating Segments | Corporate, Interest and Other

1,973

1,921

4,049

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

(463)

(1,210)

(377)

(26)

609

(240)

4,170

2,600

^[1]

United States | Operating Segments

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

3,692

3,085

4,150

(2,433)

(2,353)

(1,834)

1,942

2,133

2,449

1,700

986

411

(522)

13,640

16,096

11,894

14,596

^[1]

Europe | Operating Segments

1,387

1,400

2,727

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

629

610

870

(1,383)

(439)

(408)

381

502

635

2,503

279

(1,999)

243

(84)

1,024

5,180

946

4,907

^[1]

Africa | Operating Segments

141

297

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

675

601

945

259

(355)

(274)

263

375

539

100

197

244

(48)

428

1,507

365

1,266

^[1]

Asia and Other Countries | Operating Segments

160

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

470

466

671

(54)

(1,775)

(115)

273

224

317

251

(9)

715

(405)

3,850

3,238

2,964

2,779

^[1]

$ 415

$ 452

$ 865

[1]	Of the total Europe, Property, plant and equipment (net), Norway represented $3,893 million in 2016.

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

Dec. 31, 2017

Dec. 31, 2016

$ 16,192

$ 23,595

^[1]

Norway