Hess (HES) 10-K 21 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Jan. 31, 2019	Jun. 29, 2018
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Trading Symbol	HES
Entity Registrant Name	HESS CORP
Entity Central Index Key	4,447
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		303,034,262
Entity Public Float			$ 17,510

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current Assets:
Cash and cash equivalents	$ 2,694	$ 4,847
Accounts receivable:
From contracts with customers	771	677
Joint venture and other	230	347
Inventories	245	232
Other current assets	519	54
Total current assets	4,459	6,157
Property, plant and equipment:
Total — at cost	33,222	32,504
Less: Reserves for depreciation, depletion, amortization and lease impairment	17,139	16,312
Property, plant and equipment — net	16,083	16,192
Goodwill	360	360
Deferred income taxes	21	21
Other assets	510	382
Total Assets	21,433	23,112
Current Liabilities:
Accounts payable	495	435
Accrued liabilities	1,560	1,337
Taxes payable	81	83
Current maturities of long-term debt	67	580
Total current liabilities	2,203	2,435
Long-term debt	6,605	6,397
Deferred income taxes	421	429
Asset retirement obligations	741	753
Other liabilities and deferred credits	575	744
Total Liabilities	10,545	10,758
Hess Corporation stockholders’ equity:
Preferred stock, par value $1.00; Authorized — 20,000,000 shares, Series A 8% Cumulative Mandatory Convertible; $1,000 per share liquidation preference; Issued — 574,997 shares (2017: 575,000)	1	1
Common stock, par value $1.00; Authorized — 600,000,000 shares Issued — 291,434,534 shares (2017: 315,053,615)	291	315
Capital in excess of par value	5,386	5,824
Retained earnings	4,257	5,597
Accumulated other comprehensive income (loss)	(306)	(686)
Total Hess Corporation stockholders’ equity	9,629	11,051
Noncontrolling interests	1,259	1,303
Total equity	10,888	12,354
Total Liabilities and Equity	$ 21,433	$ 23,112

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1	$ 1
Preferred stock, shares authorized	20,000,000	20,000,000
Preferred stock, shares issued	574,997	575,000
Preferred stock, liquidation preference per share	$ 1,000	$ 1,000
Series A, cumulative mandatory convertible preferred stock - dividend rate	8.00%	8.00%
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	291,434,534	315,053,615

Statement of Consolidated Incom

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues and Non-Operating Income
Sales and other operating revenues	$ 6,323	$ 5,466	$ 4,762
Gains (losses) on asset sales, net	32	(86)	23
Other, net	111	11	54
Total revenues and non-operating income	6,466	5,391	4,839
Costs and Expenses
Marketing, including purchased oil and gas	1,771	1,267	1,063
Operating costs and expenses	1,134	1,443	1,876
Production and severance taxes	171	119	101
Exploration expenses, including dry holes and lease impairment	362	507	1,442
General and administrative expenses	473	422	414
Interest expense	399	325	338
Loss on debt extinguishment	53	0	148
Depreciation, depletion and amortization	1,883	2,883	3,244
Impairment	0	4,203	67
Total costs and expenses	6,246	11,169	8,693
Income (Loss) Before Income Taxes	220	(5,778)	(3,854)
Provision (benefit) for income taxes	335	(1,837)	2,222
Net Income (Loss)	(115)	(3,941)	(6,076)
Less: Net income (loss) attributable to noncontrolling interests	167	133	56
Net Income (Loss) Attributable to Hess Corporation	(282)	(4,074)	(6,132)
Less: Preferred stock dividends	46	46	41
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (328)	$ (4,120)	$ (6,173)
Net Income (Loss) Attributable to Hess Corporation Per Common Share
Basic	$ (1.10)	$ (13.12)	$ (19.92)
Diluted	$ (1.10)	$ (13.12)	$ (19.92)
Weighted Average Number of Common Shares Outstanding (Diluted)	298.2	314.1	309.9
Common Stock Dividends Per Share	$ 1	$ 1	$ 1

Statement of Consolidated Compr

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ (115)	$ (3,941)	$ (6,076)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	173	18	0
Income taxes on effect of hedge (gains) losses reclassified to income	0	0	0
Net effect of hedge (gains) losses reclassified to income	173	18	0
Change in fair value of cash flow hedges	330	(156)	0
Income taxes on change in fair value of cash flow hedges	(86)	0	0
Net change in fair value of cash flow hedges	244	(156)	0
Change in derivatives designated as cash flow hedges, after taxes	417	(138)	0
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	29	35	(155)
Income taxes on actuarial changes in plan liabilities	(6)	0	20
(Increase) reduction in unrecognized actuarial losses, net	23	35	(135)
Amortization of net actuarial losses	41	77	60
Income taxes on amortization of net actuarial losses	0	0	(21)
Net effect of amortization of net actuarial losses	41	77	39
Change in pension and other postretirement plans, after taxes	64	112	(96)
Foreign currency translation adjustment
Foreign currency translation adjustment	0	144	56
Asset disposition	0	900	0
Change in foreign currency translation adjustment	0	1,044	56
Other Comprehensive Income (Loss)	481	1,018	(40)
Comprehensive Income (Loss)	366	(2,923)	(6,116)
Less: Comprehensive income (loss) attributable to noncontrolling interests	167	133	56
Comprehensive Income (Loss) Attributable to Hess Corporation	$ 199	$ (3,056)	$ (6,172)

Statement of Consolidated Cash

Statement of Consolidated Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities
Net income (loss)	$ (115)	$ (3,941)	$ (6,076)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
(Gains) losses on asset sales, net	(32)	86	(23)
Depreciation, depletion and amortization	1,883	2,883	3,244
Impairment	0	4,203	67
Exploratory dry hole costs	165	268	1,064
Exploration lease and other impairment	37	44	145
Stock compensation expense	72	86	73
Noncash (gains) losses on commodity derivatives, net	182	97	0
Provision (benefit) for deferred income taxes and other tax accruals	(120)	(2,001)	2,200
Loss on debt extinguishment	53	0	148
Changes in operating assets and liabilities
(Increase) decrease in accounts receivable	(138)	(340)	96
(Increase) decrease in inventories	(12)	(64)	77
Increase (decrease) in accounts payable and accrued liabilities	88	(44)	(87)
Increase (decrease) in taxes payable	(2)	(34)	9
Changes in other operating assets and liabilities	(122)	(298)	(142)
Net cash provided by (used in) operating activities	1,939	945	795
Cash Flows from Investing Activities
Additions to property, plant and equipment - E&P	(1,854)	(1,788)	(1,974)
Additions to property, plant and equipment - Midstream	(243)	(149)	(277)
Payments for Midstream equity investments	(67)	0	0
Proceeds from asset sales, net of cash sold	607	3,296	140
Other, net	(9)	(1)	21
Net cash provided by (used in) investing activities	(1,566)	1,358	(2,090)
Cash Flows from Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	0	(153)	43
Debt with maturities of greater than 90 days – Borrowings	0	800	1,496
Debt with maturities of greater than 90 days – Repayments	(633)	(459)	(1,455)
Proceeds from issuance of Hess Midstream Partnership LP units	0	366	0
Proceeds from issuance of preferred stock	0	0	557
Proceeds from issuance of common stock	0	0	1,087
Common stock acquired and retired	(1,365)	(110)	0
Cash dividends paid	(345)	(363)	(350)
Noncontrolling interests, net	(211)	(243)	(23)
Other, net	28	(26)	(44)
Net cash provided by (used in) financing activities	(2,526)	(188)	1,311
Net Increase (Decrease) in Cash and Cash Equivalents	(2,153)	2,115	16
Cash and Cash Equivalents at Beginning of Year	4,847	2,732	2,716
Cash and Cash Equivalents at End of Year	$ 2,694	$ 4,847	$ 2,732

Statement of Consolidated Equit

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, 2015	$ 20,401	$ 0	$ 286	$ 4,127	$ 16,637	$ (1,664)	$ 19,386	$ 1,015
Net income (loss)	(6,076)	0	0	0	(6,132)	0	(6,132)	56
Other comprehensive income (loss)	(40)	0	0	0	0	(40)	(40)	0
Stock issuance	1,607	1	29	1,577	0	0	1,607	0
Share-based compensation activity, including income taxes	71	0	2	69	0	0	71	0
Dividends on preferred stock	(41)	0	0	0	(41)	0	(41)	0
Dividends on common stock	(317)	0	0	0	(317)	0	(317)	0
Noncontrolling interests, net	(14)	0	0	0	0	0	0	(14)
Balance at Dec. 31, 2016	15,591	1	317	5,773	10,147	(1,704)	14,534	1,057
Cumulative effect of adoption of new accounting standards at Dec. 31, 2016	(37)	0	0	2	(39)	0	(37)	0
Net income (loss)	(3,941)	0	0	0	(4,074)	0	(4,074)	133
Other comprehensive income (loss)	1,018	0	0	0	0	1,018	1,018	0
Share-based compensation activity, including income taxes	93	0	1	92	0	0	93	0
Dividends on preferred stock	(46)	0	0	0	(46)	0	(46)	0
Dividends on common stock	(317)	0	0	0	(317)	0	(317)	0
Common stock acquired and retired	(120)	0	(3)	(43)	(74)	0	(120)	0
Hess Midstream Partners LP units issuance	356	0	0	0	0	0	0	356
Noncontrolling interests, net	(243)	0	0	0	0	0	0	(243)
Balance at Dec. 31, 2017	12,354	1	315	5,824	5,597	(686)	11,051	1,303
Cumulative effect of adoption of new accounting standards at Dec. 31, 2017	0	0	0	0	101	(101)	0	0
Net income (loss)	(115)	0	0	0	(282)	0	(282)	167
Other comprehensive income (loss)	481	0	0	0	0	481	481	0
Share-based compensation activity, including income taxes	104	0	1	103	0	0	104	0
Dividends on preferred stock	(46)	0	0	0	(46)	0	(46)	0
Dividends on common stock	(299)	0	0	0	(299)	0	(299)	0
Common stock acquired and retired	(1,380)	0	(25)	(541)	(814)	0	(1,380)	0
Noncontrolling interests, net	(211)	0	0	0	0	0	0	(211)
Balance at Dec. 31, 2018	$ 10,888	$ 1	$ 291	$ 5,386	$ 4,257	$ (306)	$ 9,629	$ 1,259

Nature of Operations, Basis of

Nature of Operations, Basis of Presentation and Summary of Accounting Policies	12 Months Ended
	Dec. 31, 2018
Organization Consolidation And Presentation Of Financial Statements [Abstract]
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. We conduct exploration activities primarily offshore Guyana, Suriname, Canada and in the U.S. Gulf of Mexico. At the Stabroek Block (Hess 30%), offshore Guyana, we have participated in twelve significant discoveries and sanctioned in 2017 the first phase of development of the block. Our Midstream operating segment provides fee-based services, including gathering, compressing and processing natural gas and fractionating NGLs; gathering, terminaling, loading and transporting crude oil and NGLs; storing and terminaling propane, and water handling services primarily in the Bakken and Three Forks Shale plays in the Williston Basin area of North Dakota. Basis of Presentation and Principles of Consolidation: The consolidated financial statements include the accounts of Hess Corporation and entities in which we own more than a 50% voting interest. We also consolidate Hess Infrastructure Partners LP (HIP), a variable interest entity, based on our conclusion that we have the power through our 50% ownership to direct those activities that most significantly impact the economic performance of HIP, and are obligated to absorb losses or have the right to receive benefits that could potentially be significant to HIP. Our undivided interests in unincorporated oil and gas 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 2018, we adopted Accounting Standards Codification (ASC) Topic, ASC 606, Revenue from Contracts with Customers ASC 606 Retained earnings Accounts receivables from contracts with customers Consolidated Balance Sheet Statement of Consolidated Income In 2018, we adopted Accounting Standards Update (ASU) 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost Statement of Consolidated Income Other, net Operating costs and expenses General and administrative expenses Statement of Consolidated Income In 2018, we adopted ASU 2017-12, Derivatives and Hedging – Targeted Improvements to Accounting for Hedging Activities Retained earnings Accumulated other comprehensive income (loss) Consolidated Balance Sheet In 2018, the FASB issued ASU 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income Accumulated other comprehensive income (loss) Retained earnings Retained earnings Accumulated other comprehensive income (loss) Consolidated Balance Sheet In 2018, we adopted ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) Statement of Consolidated Cash Flows In 2018, we adopted ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the FASB Emerging Issues Task Force) Statement of Consolidated Cash Flows. In 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment 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 our 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: See Note 2, Revenue . 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 reported in Supplementary Oil and Gas Data , since the standardized measure requires the use of historical twelve-month average prices. Impairment of Goodwill: Goodwill is tested for impairment annually on October 1 st Cash and Cash Equivalents: Cash and cash equivalents primarily comprises cash on hand and on deposit, as well as highly liquid investments that are readily convertible into cash and have maturities of three months or less when acquired. Inventories: Unsold crude oil and NGLs are valued at the lower of cost or net realizable value. Cost is determined based on the average cost of production. Materials and supplies are valued at cost. Obsolete or surplus materials identified during periodic reviews are valued at the lower of cost or estimated net realizable value. 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. We utilize the aggregate approach for releasing disproportionate income tax effects from Accumulated other comprehensive income (loss) . 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. Changes in estimates prior to settlement result in adjustments to both the liability and related asset values, unless the field has ceased production, in which case changes are recognized in the Statement of Consolidated Income . Retirement Plans: We recognize the funded status of defined benefit postretirement plans in the Consolidated Balance Sheet . The funded status is measured as the difference between the fair value of plan assets and the projected benefit obligation. We recognize the net changes in the funded status of these plans in the year in which such changes occur. Actuarial gains and losses in excess of 10% of the greater of the benefit obligation or the market value of assets are amortized over the average remaining service period of active employees or the remaining average expected life if a plan’s participants are predominantly inactive. Derivatives: We utilize derivative instruments for financial risk management activities. In these activities, we may use futures, forwards, options and swaps, individually or in combination, to mitigate our exposure to fluctuations in prices of crude oil and natural gas, as well as changes in interest and foreign currency exchange rates. All derivative instruments are recorded at fair value in our Consolidated Balance Sheet Fair Value Measurements: We use various valuation approaches in determining fair value for financial instruments, including the market and income approaches. Our fair value measurements also include non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and our credit is considered for accrued liabilities. We also record certain nonfinancial assets and liabilities at fair value when required by GAAP. These fair value measurements are recorded in connection with business combinations, qualifying nonmonetary exchanges, the initial recognition of asset retirement obligations and any impairment of long‑lived assets, equity method investments or goodwill. We determine fair value in accordance with the fair value measurements accounting standard which established a hierarchy for the inputs used to measure fair value based on the source of the inputs, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using related market data (Level 3), including discounted cash flows and other unobservable data. Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2. When Level 1 inputs are available within a particular market, those inputs are selected for determination of fair value over Level 2 or 3 inputs in the same market. Multiple inputs may be used to measure fair value; however, the level of fair value assigned 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 fair value at the date of grant using a Black‑Scholes valuation model for employee stock options and a Monte Carlo simulation model for performance share units. Fair value of restricted stock is 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 3, 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 2018, 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 February 2016, the FASB issued ASU 2016-02, Leases , as a new ASC Topic, ASC 842. The new standard supersedes ASC 840 and will require the recognition of right-of-use assets and lease liabilities for all leases with lease terms greater than one year, including leases currently treated as operating leases under ASC 840. ASC 842 is effective for us beginning in the first quarter of 2019. We have elected to adopt ASC 842 using the modified retrospective method which allows application of the new standard prospectively from the date of adoption with a cumulative effect adjustment, if any, recorded to Retained Earnings at the date of adoption. Accordingly, comparative financial statements for periods prior to the adoption date of ASC 842 will not be affected. In addition, we have elected to apply a number of practical expedients permitted by the ASU, including not needing to reassess: (i) whether existing contracts are (or contain) leases, (ii) whether the lease classification for existing leases would differ under ASC 842, (iii) whether initial direct costs incurred for existing leases are capitalizable under ASC 842, and (iv) land easements that were not previously accounted for as leases under ASC 840. We have completed our implementation plan to adopt ASU 842, but we continue to monitor standard setting activity and our internal controls to comply with the accounting and disclosure requirements. Upon adoption on January 1, 2019, we expect to recognize operating and finance lease obligations totaling approximately $1.2 billion, of which approximately $390 million of liabilities at December 31, 2018, are included in the Consolidated Balance Sheet . We enter into various leases in the normal course of business primarily for drilling rigs, a floating storage and offloading vessel, support vessels, and office space. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses

Revenue

Revenue	12 Months Ended
	Dec. 31, 2018
Revenue From Contract With Customer [Abstract]
Revenue	Revenue from contracts with customers on a disaggregated basis in 2018 was as follows (in millions): Exploration and Production Midstream Eliminations Total United States Europe Africa Asia E&P Total Sales of our net production volumes: Crude oil revenue $ 2,832 $ 153 $ 434 $ 104 $ 3,523 $ — $ — $ 3,523 Natural gas liquids revenue 308 — — — 308 — — 308 Natural gas revenue 176 11 21 651 859 — — 859 Sales of purchased oil and gas 1,661 — 93 14 1,768 — — 1,768 Intercompany revenue — — — — — 713 (713 ) — Total revenues from contracts with customers 4,977 164 548 769 6,458 713 (713 ) 6,458 Other operating revenues (a) (135 ) — — — (135 ) — — (135 ) Total sales and other operating revenues $ 4,842 $ 164 $ 548 $ 769 $ 6,323 $ 713 $ (713 ) $ 6,323 (a) Includes gains (losses) on commodity derivatives. Exploration and Production The E&P segment recognizes revenue from the sale of crude oil, NGLs, and natural gas as performance obligations under contracts with customers are satisfied. Our responsibilities to deliver each unit of quantity of crude oil, NGL, and natural gas under these contracts represent separate, distinct performance obligations. These performance obligations are satisfied at the point in time control of each unit of quantity transfers to the customer. Generally, the control of each unit of quantity transfers to the customer upon the transfer of legal title at the point of physical delivery. Pricing is variable and is determined with reference to a particular market or pricing index, plus or minus adjustments reflecting quality or location differentials. For long-term international natural gas contracts with ship-or-pay provisions, our obligation to stand-ready to provide a minimum volume over each commitment period represents separate, distinct performance obligations. Penalties owed against future deliveries of natural gas due to delivery of volumes below minimum delivery commitments are recognized as reductions to revenue in the commitment period when the shortfall occurs. Long-term international natural gas contracts may also contain take-or-pay provisions whereby the customer is required to pay for volumes not taken that are below the minimum volume commitment, but the customer has certain make-up rights to receive shortfall volumes in subsequent periods. Shortfall payments received from customers when volumes purchased are below the minimum volume commitment are deferred upon receipt as a contract liability. Revenue is recognized at the earlier of when we deliver the make-up volumes in subsequent periods or when it becomes remote that the customer will exercise their make-up rights. Certain crude oil, NGL, and natural gas volumes are purchased by Hess from third-parties, including working interest partners and royalty owners in certain Hess-operated properties, before they are sold to customers. Where control over the crude oil, NGLs, or natural gas transfers to Hess before the volumes are transferred to the customer, revenue and the associated cost of purchased volumes are presented on a gross basis in the Statement of Consolidated Income Sales and other operating revenues Marketing, including purchased oil and gas Sales and other operating revenues Statement of Consolidated Income Contract types The following is a summary of contract types for our E&P segment: Crude oil, NGLs, and natural gas – United States (U.S.): Contracts with customers for the sale of U.S. crude oil, NGLs, and natural gas primarily include those contracts that involve the short-term sale of volumes during a specified period, and those contracts that automatically renew on a periodic basis until either party cancels. We have certain long-term contracts with customers for the sale of U.S. natural gas and NGLs that have remaining durations of less than ten years. Contracts may specify a fixed volume for delivery subject to tolerance thresholds or may specify a percentage of production to be delivered from a particular location. Pricing is determined with reference to a particular market or pricing index, plus or minus adjustments reflecting quality or location differentials. Crude oil – International: Contracts with customers for the sale of international crude oil involve the short-term sale of volumes during a specified period. These contracts specify a fixed volume for delivery subject to tolerance thresholds. Pricing is determined with reference to a particular market or pricing index, plus or minus adjustments reflecting quality or location differentials, shortly after control of the volumes transfers to the customer. Natural gas – International: Contracts with customers for the sale of natural gas are in the form of natural gas sales agreements with government entities that have durations that are aligned with the durations of production sharing contracts or other contractual arrangements with host governments. Pricing is determined using contractual formulas that are based on the price of alternative fuels as obtained from price indices and other factors. These contracts also specify a minimum volume we are obligated to make available during specified periods within the contract term and may specify minimum volumes the customer is obligated to purchase during specified periods within the contract term. If we do not deliver the volume properly nominated by the customer, the customer is entitled to a price discount on future volumes equivalent to the shortfall delivery. Under certain international natural gas sales agreements, if the customer purchases natural gas volumes below the minimum volume commitment, the customer is required to pay us for the shortfall volumes and may receive make-up volumes in subsequent periods at no additional cost. Revenue from sale of third-party purchased volumes: Crude oil, NGLs, and natural gas are purchased by Hess from third-parties, including working interest partners and royalty owners in certain Hess-operated properties, before they are sold to customers. The types of contracts with customers for the sale of third-party purchased volumes are the same as those described above. Contract Balances Our right to receive or collect payment from the customer is aligned with the timing of revenue recognition except in situations when we receive shortfall payments under contracts with take-or-pay provisions with customer make-up rights or where we recognize a liability for price discounts owed against future deliveries as a result of not shipping minimum volume commitments. At December 31, 2018 and 2017, there were no contract assets or contract liabilities, respectively. Generally, we receive payments from customers on a monthly basis, shortly after the physical delivery of the crude oil, NGLs, or natural gas. In 2018, we did not recognize any impairment losses on receivables arising from contracts with customers. Transaction Price Allocated to Remaining Performance Obligations The transaction price allocated to our wholly unsatisfied performance obligations on uncompleted contracts is variable. Further, many of our contracts with customers have durations of less than twelve months. Accordingly, we have elected under the provisions of ASC 606 Sales-based Taxes We exclude sales-based taxes that are collected from customers from the transaction price in our contracts with customers. Accordingly, revenue from contracts with customers is net of sales-based taxes that are collected from customers and remitted to taxing authorities. Midstream Our Midstream segment provides gathering, compression, processing, fractionation, storage, terminaling, loading and transportation, and water handling services. The Midstream segment has multiple long-term, fee-based commercial agreements with a marketing subsidiary of Hess, each generally with an initial ten-year term that can be extended for an additional ten-year term at the unilateral right of our Midstream segment. These contracts have minimum volumes the customer is obligated to provide each calendar quarter. The minimum volume commitments are subject to fluctuation based on nominations covering substantially all of our E&P segment’s production and projected third-party volumes that will be purchased in the Bakken. As the minimum volume commitments are subject to fluctuation, and as these contracts contain fee inflation escalators and fee recalculation mechanisms, substantially all of the transaction at contract inception is variable. The Midstream segment also provides water handling services to a subsidiary of Hess for an agreed-upon fee per barrel or the reimbursement of third-party fees. The Midstream segment’s responsibilities to provide each of the above services for each year under each of the commercial agreements are considered separate, distinct performance obligations. Revenue is recognized for each performance obligation under these commercial agreements over-time as services are rendered using the output method, measured using the amount of volumes serviced during the period. The Midstream segment has elected the practical expedient under the provisions of ASC 606

Disposition

Disposition	12 Months Ended
	Dec. 31, 2018
Disposition Of Businesses [Abstract]
Dispositions	2018: W e completed the sale of our joint venture interests in the Utica shale play in eastern Ohio in August for proceeds of $396 million, after normal closing adjustments, and recognized a pre-tax gain of $14 million ($14 million after income taxes). In addition, we completed the sale of our interests in Ghana for total consideration of $100 million, consisting of a $25 million payment that was received at closing and a further payment of $75 million that is payable to us upon the buyer receiving government approval for a Plan of Development on the Deepwater Tano Cape Three Points Block. The receipt of proceeds at closing resulted in a pre-tax gain of $10 million ($10 million after income taxes). 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). 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: 2018 2017 2016 (In millions) Equatorial Guinea (a) $ — $ 69 $ (95 ) Norway (b) — (55 ) (195 ) Income (Loss) from Continuing Operations Before Income Taxes $ — $ 14 $ (290 ) (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). The asset sales in 2018 and 2017 high grade our portfolio by divesting of lower return, mature assets to invest in higher return assets, primarily in Guyana and the Bakken, and to fund purchases of common stock and retirement of debt in 2018.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2018
Inventory Disclosure [Abstract]
Inventories	Inventories at December 31 were as follows: 2018 2017 (In millions) Crude oil and natural gas liquids $ 74 $ 59 Materials and supplies 171 173 Total Inventories $ 245 $ 232

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2018
Property Plant And Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment at December 31 were as follows: 2018 2017 (In millions) Exploration and Production Unproved properties $ 394 $ 520 Proved properties 3,124 3,162 Wells, equipment and related facilities 26,173 25,550 29,691 29,232 Midstream 3,492 3,219 Corporate and Other 39 53 Total — at cost 33,222 32,504 Less: Reserves for depreciation, depletion, amortization and lease impairment 17,139 16,312 Property, Plant and Equipment — Net $ 16,083 $ 16,192 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: 2018 2017 2016 (In millions) Balance at January 1 $ 304 $ 597 $ 1,415 Additions to capitalized exploratory well costs pending the determination of proved reserves 128 116 79 Reclassifications to wells, facilities and equipment based on the determination of proved reserves — (165 ) — Capitalized exploratory well costs charged to expense (14 ) (268 ) (897 ) Dispositions and other — 24 — Balance at December 31 $ 418 $ 304 $ 597 Number of Wells at December 31 24 12 17 During the three years ended December 31, 2018, additions to capitalized exploratory well costs primarily related to drilling at the Stabroek Block offshore Guyana. Other drilling activity included the Bunga prospect in Malaysia during 2018 and in the Gulf of Mexico during 2016. 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. Capitalized exploratory well costs charged to expense include the following: 2018: In Canada, offshore Nova Scotia (Hess 50% participating interest), the operator, BP Canada, completed drilling of the Aspy exploration well, which did not encounter commercial quantities of hydrocarbons. As a result, we expensed well costs totaling $120 million of which $106 million were incurred and expensed in 2018. 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 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. The preceding table excludes exploratory dry hole costs of $151 million in 2018 (2017: $0 million; 2016: $167 million), which were incurred and subsequently expensed in the same year. In 2018, these costs are a ssociated with the Aspy well, offshore Nova Scotia, Canada, the Pontoenoe-1 well, offshore Suriname, the Sorubim-1 well on the Stabroek Block, offshore Guyana, and the Bunga Teruntum-1 well in North Malay Basin. Exploratory well costs capitalized for greater than one year following completion of drilling were $267 million at December 31, 2018, separated by year of completion as follows (in millions): 2017 $ 97 2016 — 2015 166 2014 — 2013 4 $ 267 Gulf of Mexico: Approximately 45% 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. Following exploration and appraisal drilling activities completed by the operator in prior years on adjacent blocks to the north of our Shenzi blocks, the operator is planning to acquire 3D seismic in 2019 for use in development planning of the northern portion of the Shenzi Field. Guyana: Approximately 35% of the capitalized well costs in excess of one year relates to the Liza-4, Payara-1, Payara-2 and Snoek-1 wells on the Stabroek Block, offshore Guyana (Hess 30%), where hydrocarbons were encountered. The operator plans to integrate the Liza-4 discovery into the second phase of development, which is expected to commence production by mid-2022. The operator plans to integrate the Payara-1 and Payara-2 discoveries into the third phase of development, which is expected to commence production as early as 2023. The Snoek discovery is expected to produce into the Liza Phase 1 FPSO under a subsequent phase of development. JDA: Approximately 15% 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 has submitted a development plan concept to the regulator to facilitate commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block. Malaysia: Approximately 5% of the capitalized well costs in excess of one year relates to North Malay Basin, offshore Peninsular Malaysia (Hess 50%), where hydrocarbons were encountered in one successful exploration well drilled in the fourth quarter of 2015. In 2018, we completed four exploration wells and are conducting subsurface evaluations for consideration in future phases of field development.

Hess Infrastructure Partners LP

Hess Infrastructure Partners LP	12 Months Ended
	Dec. 31, 2018
Organization Consolidation And Presentation Of Financial Statements [Abstract]
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. 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 NGLs 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. At December 31, 2018, HIP liabilities totaling $1,105 million (2017: $1,065 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 $109 million (2017: $356 million) and Property, plant and equipment, net totaling $2,664 million (2017: $2,520 million).

Hess Midstream Partners LP - In

Hess Midstream Partners LP - Initial Public Offering	12 Months Ended
	Dec. 31, 2018
Partners Capital Notes [Abstract]
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 equally 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.

Debt

Debt	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Debt	Total debt at December 31 consisted of the following: 2018 2017 (In millions) Debt - Hess Corporation: Fixed-rate public notes: 8.1% due 2019 $ — $ 349 3.5% due 2024 298 297 4.3% due 2027 992 991 7.9% due 2029 463 500 7.3% due 2031 627 679 7.1% due 2033 537 596 6.0% due 2040 740 740 5.6% due 2041 1,234 1,234 5.8% due 2047 493 493 Total fixed-rate public notes 5,384 5,879 Capital lease obligations 269 — Financing obligations associated with floating production system 40 118 Fair value adjustments - interest rate hedging (2 ) — Total Debt - Hess Corporation $ 5,691 $ 5,997 Debt - Midstream: Fixed-rate notes: 5.6% due 2026 - HIP $ 787 $ 785 Term loan A facility - HIP 194 195 Total Debt - Midstream $ 981 $ 980 Total Debt: Current maturities of long-term debt $ 67 $ 580 Long-term debt 6,605 6,397 Total Debt $ 6,672 $ 6,977 At December 31, 2018, the maturity profile of total debt was as follows: Total Hess Corporation Midstream (In millions) 2019 $ 67 $ 56 $ 11 2020 32 17 15 2021 34 18 16 2022 171 19 152 2023 21 21 — Thereafter 6,347 5,560 787 Total debt (excluding interest) $ 6,672 $ 5,691 $ 981 Debt – Hess Corporation: Fixed-rate public notes: At December 31, 2018, Hess Corporation’s fixed-rate public notes had a gross principal amount of $5,438 million (2017: $5,938 million) and a weighted average interest rate of 5.9% (2017: 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 $3,098 million of secured debt at December 31, 2018. Capitalized interest was $20 million in 2018 (2017: $86 million; 2016: $61 million). In 2018, we paid $553 million to redeem $350 million principal amount of 8.125% notes due 2019 and to purchase other notes with a carrying value of $150 million. As a result, we recorded total losses on debt extinguishment of $53 million in 2018 (2017: $0 million; 2016: $148 million). Concurrent with the redemption of the 2019 notes, we terminated interest rate swaps with a notional amount of $350 million. Capital lease: In 2018, we entered into a sale and lease-back arrangement for a floating storage and offloading vessel (FSO) to handle produced condensate at North Malay Basin, offshore Peninsular Malaysia (Hess operated – 50%). Pursuant to the sale agreement, we received total proceeds of approximately $260 million, including our partner’s share of the proceeds which is reported in Accounts Payable Consolidated Balance Sheet. Current maturities of long-term debt Long-term debt Consolidated Balance Sheet Credit facility: Hess Corporation’s $4 billion syndicated revolving credit facility expires in January 2021, with commitments of $3.7 billion available for the final year. 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 the 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, 2018, Hess Corporation had no outstanding borrowings or letters of credit under this facility and was in compliance with this financial covenant. Other outstanding letters of credit at December 31 were as follows: 2018 2017 (In millions) Committed lines (a) $ 29 $ 29 Uncommitted lines (a) 255 217 Total $ 284 $ 246 (a) At December 31, 2018, committed and uncommitted lines have expiration dates throughout 2019. 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. 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 mended credit agreement includes a secured leverage ratio test not to exceed 3.75 to 1.00 for so long as the facilities remain secured. Hess Midstream Partners (the Partnership): The Partnership has a $300 million 4-year senior secured syndicated revolving credit facility through March 2021 that can be used for borrowings and letters of credit to fund operating activities and capital expenditures of the Partnership. Borrowings on the credit facility will generally bear interest at LIBOR plus an applicable margin of 1.275%. The interest rate is subject to adjustment based on the Partnership’s leverage ratio, which is calculated as total debt to EBITDA. If the Partnership obtains credit ratings, pricing levels will be based on the credit ratings in effect from time to time. The Partnership is subject to customary covenants in the credit agreement, including financial covenants that generally require a leverage ratio of no more than 4.5 to 1.0 for the prior four fiscal quarters. The credit facility is secured by first priority perfected liens on substantially all directly owned assets of the Partnership and its wholly-owned subsidiaries, including equity interests in subsidiaries, subject to certain customary exclusions. Outstanding borrowings under this credit facility are non-recourse to Hess Corporation.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	9. Asset Retirement Obligations The following table describes changes to and maturity of our asset retirement obligations: 2018 2017 (In millions) Balance at January 1 $ 801 $ 2,128 Liabilities incurred 68 62 Liabilities settled or disposed of (46 ) (1,464 ) Accretion expense 37 97 Revisions of estimated liabilities 1 (54 ) Foreign currency remeasurement (4 ) 32 Balance at December 31 $ 857 $ 801 Total Asset Retirement Obligations at December 31: Current portion of asset retirement obligations $ 116 $ 48 Long-term asset retirement obligations 741 753 Total at December 31 $ 857 $ 801 The liabilities incurred in 2018 include $25 million related to acquired participating interests. The liabilities settled or disposed of in 2017 primarily relate to the sale of our interests in Norway and Equatorial Guinea. 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

Retirement Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2018
Compensation And Retirement Disclosure [Abstract]
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 2018 2017 2018 2017 2018 2017 (In millions) Change in Benefit Obligation Balance at January 1, $ 2,765 $ 2,560 $ 249 $ 256 $ 87 $ 84 Service cost 30 36 12 13 2 4 Interest cost 84 93 7 9 3 3 Actuarial (gains) loss (a) (237 ) 138 (29 ) 10 (24 ) 3 Benefit payments (b) (110 ) (113 ) (19 ) (39 ) (7 ) (7 ) Plan curtailments (10 ) (3 ) (4 ) — (2 ) — Plan amendments 4 — — — — — Foreign currency exchange rate changes (34 ) 54 — — — — Balance at December 31, (c) 2,492 2,765 216 249 59 87 Change in Fair Value of Plan Assets Balance at January 1, $ 2,732 $ 2,284 $ — $ — $ — $ — Actual return on plan assets (77 ) 351 — — — — Employer contributions 59 158 19 39 7 7 Benefit payments (b) (110 ) (113 ) (19 ) (39 ) (7 ) (7 ) Foreign currency exchange rate changes (36 ) 52 — — — — Balance at December 31, 2,568 2,732 — — — — Funded Status (Plan assets greater (less) than benefit obligations) at December 31, $ 76 $ (33 ) $ (216 ) $ (249 ) $ (59 ) $ (87 ) Unrecognized Net Actuarial (Gains) Losses $ 778 $ 789 $ 47 $ 84 $ (32 ) $ (10 ) (a) The change in discount rate in 2018 resulted in total actuarial gains of approximately $235 million (2017: $170 million of actuarial losses). (b) Benefit payments include lump-sum settlement payments of approximately $32 million in 2018 (2017: $57 million). (c) At December 31, 2018, the accumulated benefit obligation for the funded and unfunded defined benefit pension Amounts recognized in the Consolidated Balance Sheet at December 31 consisted of the following: Funded Unfunded Postretirement Pension Plans Pension Plan Medical Plan 2018 2017 2018 2017 2018 2017 (In millions) Noncurrent assets $ 76 $ 22 $ — $ — $ — $ — Current liabilities — — (30 ) (18 ) (9 ) (11 ) Noncurrent liabilities — (55 ) (186 ) (231 ) (50 ) (76 ) Pension assets / (accrued benefit liability) $ 76 $ (33 ) $ (216 ) $ (249 ) $ (59 ) $ (87 ) Accumulated other comprehensive loss, pre-tax (a) $ 778 $ 789 $ 47 $ 84 $ (32 ) $ (10 ) (a) The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $581 million at December 31, 2018 (2017: $548 million deficit). The net periodic benefit cost for funded and unfunded pension plans, and the postretirement medical plan, is as follows: Pension Plans Postretirement Medical Plan 2018 2017 2016 2018 2017 2016 (In millions) Service cost $ 42 $ 49 $ 60 $ 2 $ 4 $ 4 Interest cost 91 102 107 3 3 3 Expected return on plan assets (194 ) (168 ) (166 ) — — — Amortization of unrecognized net actuarial losses (gains) 39 58 60 (2 ) — — Settlement loss 4 19 — — — — Curtailment gain — — — (2 ) — — Special termination benefit recognized — — 1 — — — Net Periodic Benefit Cost (a) $ (18 ) $ 60 $ 62 $ 1 $ 7 $ 7 (a) Net non-service pension costs are included in Other, net in the Statement of Consolidated Income. In 2018, net non-service pension costs amounted to income of $61 million (2017: $14 million of expense; 2016: $5 million of expense). In 2018, we recorded curtailment gains of $14 million to Accumulated other comprehensive Income (loss) Statement of Consolidated Income For the full year 2019, we forecast pension service costs for our pension and postretirement medical plans to be approximately $40 million and net non-service pension costs of approximately $40 million of income, which is comprised of interest cost of approximately $95 million, amortization of unrecognized net actuarial losses of approximately $45 million, and estimated expected return on plan assets of approximately $180 million. Assumptions : The weighted average actuarial assumptions used to determine Benefit obligations at December 31 and Net periodic benefit cost for the three years ended December 31 for our funded and unfunded pension plans were as follows: 2018 2017 2016 Benefit Obligations: Discount rate 3.9 % 3.3 % 3.7 % Rate of compensation increase 3.8 % 4.5 % 4.6 % Net Periodic Benefit Cost: Discount rate Service cost 3.9 % 3.7 % 4.1 % Interest cost 3.3 % 3.7 % 4.1 % Expected return on plan assets 7.2 % 7.3 % 7.4 % Rate of compensation increase 4.5 % 4.6 % 4.5 % The actuarial assumptions used to determine Benefit obligations at December 31 for the postretirement medical plan were as follows: 2018 2017 2016 Discount rate 3.9 % 3.2 % 3.5 % Initial health care trend rate 6.9 % 7.3 % 7.7 % 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, we have elected to use a split discount rate approach for all of our 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. 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, 30% fixed income securities (including cash and short‑term investment funds) and 20% 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. Fair value: The following tables provide the fair value of the financial assets of the funded pension plans at December 31, 2018 and 2017 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 Net Asset Value (d) Total (In millions) December 31, 2018 Cash and Short-Term Investment Funds $ 3 $ 47 $ — $ — $ 50 Equities: U.S. equities (domestic) 654 — — — 654 International equities (non-U.S.) 92 29 — 288 409 Global equities (domestic and non-U.S.) 2 203 — — 205 Fixed Income: Treasury and government issued (a) — 240 — — 240 Government related (b) — 37 — — 37 Mortgage-backed securities (c) — 159 — 27 186 Corporate — 272 — 31 303 Other: Hedge funds — — — 135 135 Private equity funds — — — 170 170 Real estate funds 49 — 61 50 160 Diversified commodities funds — 19 — — 19 Total investments $ 800 $ 1,006 $ 61 $ 701 $ 2,568 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 34 — 296 434 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) — 139 1 26 166 Corporate — 182 — 6 188 Other: Hedge funds — — — 187 187 Private equity funds — — — 140 140 Real estate funds 63 — 2 92 157 Diversified commodities funds — 24 — — 24 Total investments $ 990 $ 991 $ 4 $ 747 $ 2,732 (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. (d) Includes certain investments that have been valued using the net asset value practical expedient, and therefore have not been categorized in the fair value hierarchy. The inclusion of such amounts in the above table is intended to aid reconciliation of investments categorized in the fair value hierarchy to total pension plan assets. The following describes the financial assets of the funded pension plans: Cash and short‑term investment funds - Consists of cash on hand and short-term investment funds that provide for daily investments and redemptions. Cash on hand is classified as Level 1 and short‑term investment funds are classified as Level 2. Equities - Consists of individually held or commingled funds of U.S. and International equity securities. Equity securities, which are individually held and are traded actively on exchanges, are classified as Level 1. Commingled funds, consisting primarily of equity securities, are valued using the net asset value (NAV) per fund share derived from quoted prices in active markets of the underlying securities. These funds are classified as Level 2 where they have readily determinable fair values, otherwise they are classified under the NAV practical expedient. Fixed income investments - Consists 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 based on 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. Certain fixed income investments are commingled funds that are valued at the NAV per fund share derived indirectly from observable inputs or from quoted prices in less liquid markets of the underlying securities. These funds are classified as Level 2 where they have readily determinable fair values, otherwise they are classified under the NAV practical expedient. Other investments - Consists of exchange‑traded real estate investment trust securities, which are classified as Level 1. Commingled funds and limited partnership investments in hedge funds, private equity and real estate funds are valued at the NAV per fund share derived using information provided by fund managers which include various inputs such as discounted future cash flows, market based comparable data and independent appraisals from third parties. These funds are classified as Level 2 or 3 where they have readily determinable fair values, otherwise they are classified under the NAV practical expedient. 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: Fixed Real Estate Income Funds Total (In millions) Balance at January 1, 2017 $ 2 $ 8 $ 10 Actual return on plan assets — — — Purchases, sales or other settlements 1 (6 ) (5 ) Net transfers in (out) of Level 3 (1 ) — (1 ) Balance at December 31, 2017 2 2 4 Actual return on plan assets — 1 1 Purchases, sales or other settlements (2 ) 58 56 Net transfers in (out) of Level 3 — — — Balance at December 31, 2018 $ — $ 61 $ 61 Contributions and estimated future benefit payments : We expect to contribute approximately $40 million to our funded pension plans in 2019. 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): 2019 $ 142 2020 139 2021 135 2022 139 2023 140 Years 2024 to 2028 722 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 $19 million in 2018 for contributions to these plans (2017: $22 million; 2016: $25 million).

Share-based Compensation

Share-based Compensation	12 Months Ended
	Dec. 31, 2018
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 (Restricted stock), performance share units (PSUs) and stock options to our employees. At December 31, 2018, the total number of authorized common stock under the LTIP, as amended, was 51.5 million shares, of which we have 19.0 million shares available for issuance. S hare‑based compensation expense consisted of the following: 2018 2017 2016 (In millions) Restricted stock $ 40 $ 56 $ 45 Stock options 10 9 7 Performance share units 22 21 21 Share-based compensation expense before income taxes $ 72 $ 86 $ 73 Income tax benefit on share-based compensation expense $ — $ 1 $ 28 Based on share‑based compensation awards outstanding at December 31, 2018, unearned compensation expense, before income taxes, will be recognized in future years as follows (in millions): 2019: $57, 2020: $30 and 2021: $6. Our share-based compensation plans can be summarized as follows: Restricted stock: Restricted stock generally vests equally on an annual basis over a three-year term and are valued based on the prevailing market price of our common stock on the date of grant. The following is a summary of restricted stock award activity in 2018: Shares of Restricted Common Stock Weighted - Average Price on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2018 3,202 $ 54.04 Granted 1,258 50.78 Vested (a) (1,099 ) 65.80 Forfeited (480 ) 50.63 Outstanding at December 31, 2018 2,881 $ 48.70 (a) In 2018, restricted stock with fair values of $54 million were vested (2017: $37 million; 2016: $41 million). PSUs: PSUs generally vest three years from the date of grant and are valued based on the prevailing market price of our common stock 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. The following is a summary of PSU activity in 2018: Performance Share Units Weighted - Average Fair Value on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2018 1,146 $ 58.78 Granted 278 59.65 Vested (a) (313 ) 76.64 Forfeited (48 ) 53.62 Outstanding at December 31, 2018 1,063 $ 53.98 (a) In 2018, PSU’s with fair value of $9 million were vested (2017: $10 million; 2016: $15 million). The following weighted average assumptions were utilized to estimate the fair value of PSU awards: 2018 2017 2016 Risk free interest rate 2.39 % 1.55 % 0.96 % Stock price volatility 0.400 0.387 0.329 Contractual term in years 3.0 3.0 3.0 Grant date price of Hess common stock $ 48.48 $ 51.03 $ 44.31 Stock options: Stock options vest over three years from the date of grant, have a 10‑year term, and the exercise price equals market price of the common stock on the date of grant. The following is a summary of stock options activity in 2018: Number of options (In thousands) Weighted Average Exercise Price per Share Weighted Average Remaining Contractual Term Outstanding at January 1, 2018 6,482 $ 66.84 3.6 years Granted 683 48.48 Exercised (564 ) 55.84 Forfeited (1,431 ) 80.23 Outstanding at December 31, 2018 5,170 $ 61.91 4.3 years At December 31, 2018, there were 5.2 million outstanding stock options (3.9 million exercisable) with a weighted average remaining contractual life of 4.3 years (2.9 years for exercisable options) and an aggregated intrinsic value of 0 (0 for exercisable options). The following weighted average assumptions were utilized to estimate the fair value of stock options: 2018 2017 2016 Risk free interest rate 2.74 % 2.17 % 1.47 % Stock price volatility 0.322 0.333 0.326 Dividend yield 2.06 % 1.96 % 2.26 % Expected life in years 6.0 6.0 6.0 Weighted average fair value per option granted $ 13.69 $ 14.51 $ 11.33 In estimating the fair value of PSUs and stock options, 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 Corporation using the expected term.

Exit and Disposal Costs

Exit and Disposal Costs	12 Months Ended
	Dec. 31, 2018
Restructuring And Related Activities [Abstract]
Exit and Disposal Costs	In 2018, we incurred severance expense of $38 million (2017: $18 million; 2016: $55 million) and paid accrued severance costs of $40 million (2017: $48 million; 2016: $52 million). The severance expenses incurred during the three-year period resulted from asset sales and cost savings initiatives in response to low crude oil prices. At December 31, 2018, we had accrued liabilities for severance costs of $4 million (2017: $6 million) and accrued liabilities for exit cost provisions of $85 million (2017: $28 million). Accrued severance costs are expected to be paid in 2019, and accrued exit costs will be paid over the next several years.

Impairment

Impairment	12 Months Ended
	Dec. 31, 2018
Asset Impairment Charges [Abstract]
Impairment	13. 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 3, 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. Each of the valuation methods used in the determination of the impairment charges above represent Level 3 fair value measurements.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	14. Income Taxes The provision (benefit) for income taxes consisted of: 2018 2017 2016 (a) (In millions) United States Federal Current $ 1 $ (23 ) $ (27 ) Deferred taxes and other accruals (74 ) (6 ) 1,948 State (45 ) — 23 (118 ) (29 ) 1,944 Foreign Current (b) 455 179 36 Deferred taxes and other accruals (2 ) (1,987 ) 235 453 (1,808 ) 271 Total 335 (1,837 ) 2,215 Adjustment of deferred taxes for foreign income tax law changes — — 7 Total Provision (Benefit) For Income Taxes $ 335 $ (1,837 ) $ 2,222 (a) Includes charges of $3,749 million to establish valuation allowances on net deferred tax assets. (b) Primarily comprised of Libya in 2018 and 2017. Income (loss) before income taxes consisted of the following: 2018 2017 2016 (In millions) United States (a) $ (219 ) $ (2,784 ) $ (2,431 ) Foreign 439 (2,994 ) (1,423 ) Total Income (Loss) Before Income Taxes $ 220 $ (5,778 ) $ (3,854 ) (a) Includes substantially all of our interest expense, corporate expense and the results of commodity hedging activities. The difference between our effective income tax rate and the U.S. statutory rate is reconciled below: 2018 2017 2016 U.S. statutory rate 21.0 % 35.0 % 35.0 % Effect of foreign operations (a) 141.2 17.4 4.6 State income taxes, net of Federal income tax (18.9 ) — 1.9 Change in enacted tax laws (b) — (23.6 ) (0.2 ) Valuation allowance adjustment with tax law change (b) — 23.6 — Rate differential on U.S. loss — (4.1 ) — Gains on asset sales, net — (2.2 ) — Impairment — — (2.1 ) Valuation allowance on current year operations 55.2 (14.9 ) — Valuation allowance against previously benefitted deferred tax assets — 0.1 (97.3 ) Noncontrolling interest in partnership (15.9 ) 0.8 0.5 Intraperiod allocation (37.3 ) — — Equity compensation shortfall 6.3 (0.3 ) — Other 0.8 — (0.1 ) Total 152.4 % 31.8 % (57.7 ) % (a) The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the mix of income among high, primarily Libya, 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 $1,336 million reduction to our U.S. net deferred tax asset at December 31, 2017, with a corresponding reduction in the previously established U.S. valuation allowance. The components of deferred tax liabilities and deferred tax assets at December 31 were as follows: 2018 2017 (In millions) Deferred Tax Liabilities Property, plant and equipment and investments $ (853 ) $ (629 ) Other (77 ) (24 ) Total Deferred Tax Liabilities (930 ) (653 ) Deferred Tax Assets Net operating loss carryforwards 4,239 4,029 Tax credit carryforwards 134 138 Property, plant and equipment and investments 416 746 Accrued compensation, deferred credits and other liabilities 232 283 Asset retirement obligations 225 212 Other 161 36 Total Deferred Tax Assets 5,407 5,444 Valuation allowances (a) (4,877 ) (5,199 ) Total deferred tax assets, net of valuation allowances 530 245 Net Deferred Tax Assets (Liabilities) $ (400 ) $ (408 ) (a) In 2018, the valuation allowance decreased by $322 million (2017: decrease of $251 million; 2016: increase of $3,872). In the Consolidated Balance Sheet 2018 2017 (In millions) Deferred income taxes (long-term asset) $ 21 $ 21 Deferred income taxes (long-term liability) (421 ) (429 ) Net Deferred Tax Assets (Liabilities) $ (400 ) $ (408 ) At December 31, 2018, we have recognized a gross deferred tax asset related to net operating loss carryforwards of $4,239 million before application of valuation allowances. The deferred tax asset is comprised of $1,382 million attributable to foreign net operating losses which begin to expire in 2025, $2,386 million attributable to U.S. Federal operating losses which begin to expire in 2035, and $471 million attributable to losses in various U.S. states which begin to expire in 2019. The deferred tax asset attributable to foreign net operating losses, net of valuation allowances, is At December 31, 2018, the Balance Sheet reflects a $4,877 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, 2018 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 Company completed its review of previously recorded provisional income tax amounts related to the U.S. Tax Cuts and Jobs Act (“Act”) and concluded that additional information, interpretation and guidance that became available during the twelve-month measurement period did not alter the Company’s accounting as reported in its Consolidated Financial Statements as of December 31, 2017. There were no adjustments deemed necessary in the period ended December 31, 2018. Below is a reconciliation of the gross beginning and ending amounts of unrecognized tax benefits: 2018 2017 2016 (In millions) Balance at January 1 $ 205 $ 424 $ 604 Additions based on tax positions taken in the current year 19 14 19 Additions based on tax positions of prior years 36 4 113 Reductions based on tax positions of prior years (78 ) (147 ) (274 ) Reductions due to settlements with taxing authorities (10 ) (85 ) (27 ) Reductions due to lapses in statutes of limitation (4 ) (5 ) (11 ) Balance at December 31 $ 168 $ 205 $ 424 The December 31, 2018 balance of unrecognized tax benefits includes $7 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 $2 million and $8 million due to settlements with taxing authorities or other resolutions, as well as lapses in statutes of limitation. At December 31, 2018, our accrued interest and penalties related to unrecognized tax benefits is $3 million (2017: $23 million). 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.

Basic and Diluted Earnings Per

Basic and Diluted Earnings Per Common Share	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Basic and Diluted Earnings Per Common Share	15. Basic and Diluted Earnings Per Common Share The Net income (loss) and weighted average number of common shares used in basic and diluted earnings per share computation were as follows: 2018 2017 2016 (In millions) Net Income (Loss) Attributable to Hess Corporation Common Stockholders: Net income (loss) $ (115 ) $ (3,941 ) $ (6,076 ) Less: Net income (loss) attributable to noncontrolling interests 167 133 56 Less: Preferred stock dividends 46 46 41 Net income (loss) attributable to Hess Corporation Common Stockholders $ (328 ) $ (4,120 ) $ (6,173 ) Weighted Average Number of Common Shares Outstanding: Basic 298.2 314.1 309.9 Effect of dilutive securities Restricted common stock — — — Stock options — — — Performance share units — — — Mandatory Convertible Preferred stock — — — Diluted 298.2 314.1 309.9 Net Income (Loss) Attributable to Hess Corporation per Common Share: Basic $ (1.10 ) $ (13.12 ) $ (19.92 ) Diluted $ (1.10 ) $ (13.12 ) $ (19.92 ) Antidilutive shares excluded from the computation of diluted shares: Restricted common stock 2.9 3.3 3.3 Stock options 5.5 6.4 6.9 Performance share units 1.1 0.6 0.9 Common shares from conversion of preferred stock 12.7 12.8 11.2

Common and Preferred Stock

Common and Preferred Stock	12 Months Ended
	Dec. 31, 2018
Stockholders Equity Note [Abstract]
Common and Preferred Stock	The following table provides the changes in our outstanding common shares: 2018 2017 2016 (In millions) Balance at January 1 315.1 316.5 286.0 Shares issued — — 28.8 Activity related to restricted stock awards, net 0.8 0.8 1.1 Stock options exercised 0.6 0.2 0.2 PSU vested 0.1 0.2 0.4 Shares repurchased (25.2 ) (2.6 ) — Balance at December 31 291.4 315.1 316.5 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 volume weighted average share price (“VWAP”) over a period of twenty-consecutive trading days ending January 28, 2019, subject to anti-dilution adjustments. See Note 15, Basic and Diluted Earnings Per Common Share Note 22, Subsequent Event We also entered into capped call transactions on 12.55 million covered shares that were expected generally to reduce the potential dilution to our common stock upon conversion of the Convertible Preferred Stock if the VWAP for any individual day during the period of twenty consecutive trading days ending January 28, 2019 exceeded $45.83 per share, subject to anti-dilution adjustments. On any day during the twenty consecutive trading days ending January 28, 2019, if the daily VWAP is between $45.83 and $53.625, the value of the capped call transactions for that day will be the proportionate covered shares multiplied by the difference between the VWAP for that day and $45.83. The number of common shares to be delivered by the counterparties to us will be the sum of each daily calculation during the twenty-consecutive trading day period. The premium paid for the capped call transactions was $37 million, which was recorded against Capital in excess of par Statement of Consolidated Equity Note 22, Subsequent Event. Common Stock Repurchase Plan : In 2018, we repurchased 25.2 million shares of our common stock (2017: 2.6 million shares) for $1,380 million (2017: $120 million), at an average cost per share of $54.85 (2017: $45.67). There were no repurchases in 2016. Common stock dividends : In 2018, 2017 and 2016, cash dividends declared on common stock totaled $1.00 per share ($0.25 per quarter).

Supplementary Cash Flow Informa

Supplementary Cash Flow Information	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Supplementary Cash Flow Information	17. Supplementary Cash Flow Information The following information supplements the Statement of Consolidated Cash Flows 2018 2017 2016 (In millions) Cash Flows from Operating Activities Interest paid $ (394 ) $ (314 ) $ (338 ) Net income taxes (paid) refunded (463 ) (210 ) 132 Cash Flows from Investing Activities Capital expenditures incurred - E&P $ (1,909 ) $ (1,852 ) $ (1,638 ) Increase (decrease) in related liabilities 55 64 (336 ) Additions to property, plant and equipment - E&P $ (1,854 ) $ (1,788 ) $ (1,974 ) Capital expenditures incurred - Midstream $ (271 ) $ (121 ) $ (283 ) Increase (decrease) in related liabilities 28 (28 ) 6 Additions to property, plant and equipment - Midstream $ (243 ) $ (149 ) $ (277 )

Leased Assets

Leased Assets	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
Leased Assets	We and certain of our subsidiaries lease drilling rigs, support vessels, 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, 2018, future minimum rental payments applicable to non‑cancelable operating leases with remaining terms in excess of one year (other than oil and gas property leases) are as follows (in millions): 2019 $ 355 2020 156 2021 65 2022 64 2023 64 Remaining years 198 Total Minimum Lease Payments 902 Less: Income from subleases 114 Net Minimum Lease Payments $ 788 Rental expense was as follows: 2018 2017 2016 (In millions) Total rental expense $ 154 $ 123 $ 106 Less: Income from subleases 8 10 5 Net Rental Expense $ 146 $ 113 $ 101

Guarantees, Contingencies and C

Guarantees, Contingencies and Commitments	12 Months Ended
	Dec. 31, 2018
Commitments And Contingencies Disclosure [Abstract]
Guarantees, Contingencies and Commitments	19. Guarantees, Contingencies and Commitments Guarantees and Contingencies 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 was a defective product and that these producers and refiners 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 three remaining active cases, filed by Pennsylvania, Rhode Island, and Maryland. In June 2014, the Commonwealth of Pennsylvania filed a lawsuit alleging that we and all major oil companies with operations in Pennsylvania, have damaged the groundwater by introducing thereto gasoline with MTBE. The Pennsylvania suit has been forwarded to the existing MTBE multidistrict litigation pending in the Southern District of New York. 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 state court, was served on us in January 2018 and has been removed to Federal court by the defendants. 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 our former terminal did not store or use contaminants which are of concern in the river sediments and could not have contributed contamination along the river’s length. Further, there are numerous other parties who we expect will bear the cost of remediation and damages. 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, Texas. 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 is not expected to have a material adverse effect on our financial condition, results of operations or cash flows. Unconditional Purchase Obligations and Commitments The following table shows aggregate information for certain unconditional purchase obligations and commitments at December 31, 2018, which are not included elsewhere within these Consolidated Financial Statements Payments Due by Period 2020 and 2022 and Total 2019 2021 2023 Thereafter (In millions) Capital expenditures $ 1,069 $ 443 $ 551 $ 75 $ — Operating expenses 433 219 99 61 54 Transportation and related contracts 1,050 212 401 336 101

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Segment Information	20. 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, NGLs and natural gas. Production operations over the three years ended December 31, 2018 were primarily in the United States (U.S.), Denmark, the JDA and Malaysia, and from divested assets, including Equatorial Guinea (until November 2017) and Norway (until December 2017). The Midstream operating segment provides fee-based services including crude oil and natural gas gathering, processing of natural gas and the fractionation of NGLs, transportation of crude oil by rail car, terminaling and loading crude oil and NGLs, storing and terminaling propane, and water handling services 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 (in millions): Exploration and Production Midstream Corporate, Interest and Other Eliminations Total 2018 Sales and Other Operating Revenues - Third-parties $ 6,323 $ — $ — $ — $ 6,323 Intersegment Revenues — 713 — (713 ) — Sales and Other Operating Revenues $ 6,323 $ 713 $ — $ (713 ) $ 6,323 Net Income (Loss) Attributable to Hess Corporation $ 51 $ 120 $ (453 ) $ — $ (282 ) Interest Expense — 60 339 — 399 Depreciation, Depletion and Amortization 1,748 127 8 — 1,883 Provision (Benefit) for Income Taxes (a) 391 38 (94 ) — 335 Investment in Affiliates 126 67 — — 193 Identifiable Assets 16,109 3,285 2,039 — 21,433 Capital Expenditures 1,909 271 — — 2,180 2017 Sales and Other Operating Revenues - Third-parties $ 5,460 $ 6 $ — $ — $ 5,466 Intersegment Revenues — 611 — (611 ) — Sales and Other Operating Revenues $ 5,460 $ 617 $ — $ (611 ) $ 5,466 Net Income (Loss) 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 Sales and Other Operating Revenues - Third-parties $ 4,755 $ 7 $ — $ — $ 4,762 Intersegment Revenues — 562 — (562 ) — Sales and Other Operating Revenues $ 4,755 $ 569 $ — $ (562 ) $ 4,762 Net Income (Loss) 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 Capital Expenditures 1,638 283 — — 1,921 (a) The provision for income taxes in the Midstream segment in 2018 and 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) 2018 Sales and Other Operating Revenues $ 4,842 $ 164 $ 548 $ 769 $ — $ 6,323 Net Income (Loss) Attributable to Hess Corporation 131 42 36 (38 ) (453 ) (282 ) Depreciation, Depletion and Amortization 1,424 37 19 395 8 1,883 Provision (Benefit) for Income Taxes (25 ) 15 430 9 (94 ) 335 Identifiable Assets 13,250 1,033 395 4,716 2,039 21,433 Property, Plant and Equipment (Net) 11,653 906 355 3,154 15 16,083 Capital Expenditures 1,543 8 9 620 — 2,180 2017 Sales and Other Operating Revenues $ 3,692 $ 629 $ 675 $ 470 $ — $ 5,466 Net Income (Loss) 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 Sales and Other Operating Revenues $ 3,085 $ 610 $ 601 $ 466 $ — $ 4,762 Net Income (Loss) 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 Capital Expenditures 1,400 59 10 452 — 1,921

Financial Risk Management Activ

Financial Risk Management Activities	12 Months Ended
	Dec. 31, 2018
Derivative Instruments And Hedging Activities Disclosure [Abstract]
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 produce 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 business with the intent of reducing exposure to foreign currency fluctuations. At December 31, 2018, 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. 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 outstanding financial risk management derivative contracts related to WTI instruments as of the dates shown below were as follows: December 31, 2018 December 31, 2017 Calendar year program 2019 2018 Instrument type Puts Collars Crude oil volumes (millions of barrels) 34.7 42.0 Ceiling price N/A $ 65 Floor price $ 60 $ 50 At December 31, 2017, we had WTI crude oil price collars for calendar year 2018 with a monthly floor price of $50 per barrel and a monthly ceiling price of $65 per barrel for 115,000 bopd. In the first quarter of 2018, we bought back the WTI $65 call options within the crude oil price collars for the period of May 1, 2018 through December 31, 2018. In 2018, The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows: December 31, 2018 December 31, 2017 (In millions) Foreign exchange $ 16 $ 52 Interest rate swaps $ 100 $ 450 The table below reflects the gross and net fair values of risk management derivative instruments and their respective financial statement caption in the Consolidated Balance Sheet Assets Liabilities (In millions) December 31, 2018 Derivative Contracts Designated as Hedging Instruments Commodity - Other current assets $ 484 $ — Interest rate - Other liabilities and deferred credits (noncurrent) — (2 ) Total derivative contracts designated as hedging instruments 484 (2 ) Gross fair value of derivative contracts 484 (2 ) Master netting arrangements — — Net Fair Value of Derivative Contracts $ 484 $ (2 ) 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 - Accounts receivable: Joint venture and other 1 — Total derivative contracts not designated as hedging instruments 1 (2 ) Gross fair value of derivative contracts 1 (13 ) Master netting arrangements — — Net Fair Value of Derivative Contracts $ 1 $ (13 ) All fair values above are based on Level 2 inputs. Impact on statement of consolidated income from derivative contracts designated as hedging instruments: Crude oil derivatives: In 2018, c rude oil price hedging contracts decreased Sales and other operating revenues by $161 million (2017: decrease of $ 34 million; 2016: $0). At December 31, 2018, pre-tax deferred gains in Accumulated other comprehensive income (loss) related to outstanding crude oil price hedging contracts were $365 million, of which all will be reclassified into earnings during the next 12 months as the hedged crude oil sales are recognized in earnings. Interest rate swaps designated as fair value hedges: At December 31, 2018, we had interest rate swaps with gross notional amounts of $100 million (2017: $450 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 2018, we terminated interest rate swaps with a gross notional amount of $350 million and paid $3 million (2017: $0; 2016: $5 million proceeds) See Note 8, Debt . 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 2018, the change in fair value of interest rate swaps was an increase in the derivative liability of $ 1 million (2017: $4 million increase in liability; 2016: $6 million increase in asset) with a corresponding adjustment in the carrying value of the hedged fixed‑rate debt. 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 for a payment of $3 million as part of the refinancing that occurred later in the year. See Note 8, Debt . Impact on statement of consolidated income from derivative contracts not designated as hedging instruments: Crude oil collars: In 2018, noncash adjustments to de-designated c rude oil price hedging contracts decreased Sales and other operating revenues by $22 million (2017: decrease of $25 million). Foreign exchange : Total foreign exchange gains and losses were a loss of $5 million in 2018 (2017: gain of $15 million; 2016: gain of $26 million) and are reported in in Revenues and non-operating income in the A component of foreign exchange gains or losses is the result of foreign exchange derivative contracts that are not designated as hedges, which amounted to a loss of $2 million in 2018 (2017: gain of $3 million; 2016: gain of $62 million). After‑tax foreign currency translation adjustments included in the Statement of Consolidated Comprehensive Income Note 3, Dispositions 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. At December 31, 2018, our Accounts receivable were concentrated with the following counterparty industry segments: Financial Institutions — 34%, Integrated companies — 24%, Independent E&P companies — 22%, National oil companies — 7% Refining and marketing companies — 5%, Storage and transportation companies — 3%, and Others — 5%. 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, 2018, we had outstanding letters of credit totaling $284 million (2017: $246 million). Fair Value Measurement: At December 31, 2018, outstanding total debt, excluding capital leases, was substantially comprised of fixed rate debt instruments with a carrying value of $6,403 million and a fair value of $6,225 million, based on Level 2 inputs in the fair value measurement hierarchy. We also have short-term financial instruments, primarily cash equivalents, accounts receivable and accounts payable, for which the carrying value approximated fair value at December 31, 2018 and December 31, 2017.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2018
Subsequent Events [Abstract]
Subsequent Events	On January 31, 2019, the 8.00% Series A Mandatory Convertible Preferred Stock (Preferred Stock) automatically converted into shares of common stock at a rate of 21.822 shares of common stock per share of Preferred Stock. In total, the Preferred Stock was converted into approximately 12.5 million shares of common stock. In connection with the Preferred Stock offering in 2016, the Company entered into capped call transactions to reduce the potential dilution to the Company’s common stock upon conversion of the Preferred Stock, subject to a cap. The Company received approximately 0.9 million shares of common stock upon settlement of the capped call transactions. As a result, the net number of common shares issued by the Company upon conversion of the Preferred Stock was approximately 11.6 million shares.

Nature of Operations, Basis o_2

Nature of Operations, Basis of Presentation and Summary of Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Basis of Presentation and Principles of Consolidation	Basis of Presentation and Principles of Consolidation: The consolidated financial statements include the accounts of Hess Corporation and entities in which we own more than a 50% voting interest. We also consolidate Hess Infrastructure Partners LP (HIP), a variable interest entity, based on our conclusion that we have the power through our 50% ownership to direct those activities that most significantly impact the economic performance of HIP, and are obligated to absorb losses or have the right to receive benefits that could potentially be significant to HIP. Our undivided interests in unincorporated oil and gas 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 2018, we adopted Accounting Standards Codification (ASC) Topic, ASC 606, Revenue from Contracts with Customers ASC 606 Retained earnings Accounts receivables from contracts with customers Consolidated Balance Sheet Statement of Consolidated Income In 2018, we adopted Accounting Standards Update (ASU) 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost Statement of Consolidated Income Other, net Operating costs and expenses General and administrative expenses Statement of Consolidated Income In 2018, we adopted ASU 2017-12, Derivatives and Hedging – Targeted Improvements to Accounting for Hedging Activities Retained earnings Accumulated other comprehensive income (loss) Consolidated Balance Sheet In 2018, the FASB issued ASU 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income Accumulated other comprehensive income (loss) Retained earnings Retained earnings Accumulated other comprehensive income (loss) Consolidated Balance Sheet In 2018, we adopted ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) Statement of Consolidated Cash Flows In 2018, we adopted ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the FASB Emerging Issues Task Force) Statement of Consolidated Cash Flows. In 2017, the FASB issued ASU 2017-04, Intangibles – Goodwill and Other – Simplifying the Test for Goodwill Impairment
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 our Statement of Consolidated Income . Actual results could differ from those estimates. Estimates made by management include oil and gas reserves, asset and other valuations, depreciable lives, pension liabilities, legal and environmental obligations, asset retirement obligations and income taxes.
Revenue Recognition	Revenue Recognition: See Note 2, Revenue .
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 reported in Supplementary Oil and Gas Data , since the standardized measure requires the use of historical twelve-month average prices.
Impairment of Goodwill	Impairment of Goodwill: Goodwill is tested for impairment annually on October 1 st
Cash and Cash Equivalents	Cash and Cash Equivalents: Cash and cash equivalents primarily comprises cash on hand and on deposit, as well as highly liquid investments that are readily convertible into cash and have maturities of three months or less when acquired.
Inventories	Inventories: Unsold crude oil and NGLs are valued at the lower of cost or net realizable value. Cost is determined based on the average cost of production. Materials and supplies are valued at cost. Obsolete or surplus materials identified during periodic reviews are valued at the lower of cost or estimated net realizable value.
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. We utilize the aggregate approach for releasing disproportionate income tax effects from Accumulated other comprehensive income (loss) .
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. Changes in estimates prior to settlement result in adjustments to both the liability and related asset values, unless the field has ceased production, in which case changes are recognized in the Statement of Consolidated Income .
Retirement Plans	Retirement Plans: We recognize the funded status of defined benefit postretirement plans in the Consolidated Balance Sheet . The funded status is measured as the difference between the fair value of plan assets and the projected benefit obligation. We recognize the net changes in the funded status of these plans in the year in which such changes occur. Actuarial gains and losses in excess of 10% of the greater of the benefit obligation or the market value of assets are amortized over the average remaining service period of active employees or the remaining average expected life if a plan’s participants are predominantly inactive.
Derivatives	Derivatives: We utilize derivative instruments for financial risk management activities. In these activities, we may use futures, forwards, options and swaps, individually or in combination, to mitigate our exposure to fluctuations in prices of crude oil and natural gas, as well as changes in interest and foreign currency exchange rates. All derivative instruments are recorded at fair value in our Consolidated Balance Sheet
Fair Value Measurements	Fair Value Measurements: We use various valuation approaches in determining fair value for financial instruments, including the market and income approaches. Our fair value measurements also include non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and our credit is considered for accrued liabilities. We also record certain nonfinancial assets and liabilities at fair value when required by GAAP. These fair value measurements are recorded in connection with business combinations, qualifying nonmonetary exchanges, the initial recognition of asset retirement obligations and any impairment of long‑lived assets, equity method investments or goodwill. We determine fair value in accordance with the fair value measurements accounting standard which established a hierarchy for the inputs used to measure fair value based on the source of the inputs, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using related market data (Level 3), including discounted cash flows and other unobservable data. Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2. When Level 1 inputs are available within a particular market, those inputs are selected for determination of fair value over Level 2 or 3 inputs in the same market. Multiple inputs may be used to measure fair value; however, the level of fair value assigned 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 fair value at the date of grant using a Black‑Scholes valuation model for employee stock options and a Monte Carlo simulation model for performance share units. Fair value of restricted stock is 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 3, 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 2018, 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 February 2016, the FASB issued ASU 2016-02, Leases , as a new ASC Topic, ASC 842. The new standard supersedes ASC 840 and will require the recognition of right-of-use assets and lease liabilities for all leases with lease terms greater than one year, including leases currently treated as operating leases under ASC 840. ASC 842 is effective for us beginning in the first quarter of 2019. We have elected to adopt ASC 842 using the modified retrospective method which allows application of the new standard prospectively from the date of adoption with a cumulative effect adjustment, if any, recorded to Retained Earnings at the date of adoption. Accordingly, comparative financial statements for periods prior to the adoption date of ASC 842 will not be affected. In addition, we have elected to apply a number of practical expedients permitted by the ASU, including not needing to reassess: (i) whether existing contracts are (or contain) leases, (ii) whether the lease classification for existing leases would differ under ASC 842, (iii) whether initial direct costs incurred for existing leases are capitalizable under ASC 842, and (iv) land easements that were not previously accounted for as leases under ASC 840. We have completed our implementation plan to adopt ASU 842, but we continue to monitor standard setting activity and our internal controls to comply with the accounting and disclosure requirements. Upon adoption on January 1, 2019, we expect to recognize operating and finance lease obligations totaling approximately $1.2 billion, of which approximately $390 million of liabilities at December 31, 2018, are included in the Consolidated Balance Sheet . We enter into various leases in the normal course of business primarily for drilling rigs, a floating storage and offloading vessel, support vessels, and office space. In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses

Revenue (Tables)

Revenue (Tables)	12 Months Ended
	Dec. 31, 2018
Revenue From Contract With Customer [Abstract]
Summary of Revenue from Contracts with Customers on a Disaggregated Basis	Exploration and Production Midstream Eliminations Total United States Europe Africa Asia E&P Total Sales of our net production volumes: Crude oil revenue $ 2,832 $ 153 $ 434 $ 104 $ 3,523 $ — $ — $ 3,523 Natural gas liquids revenue 308 — — — 308 — — 308 Natural gas revenue 176 11 21 651 859 — — 859 Sales of purchased oil and gas 1,661 — 93 14 1,768 — — 1,768 Intercompany revenue — — — — — 713 (713 ) — Total revenues from contracts with customers 4,977 164 548 769 6,458 713 (713 ) 6,458 Other operating revenues (a) (135 ) — — — (135 ) — — (135 ) Total sales and other operating revenues $ 4,842 $ 164 $ 548 $ 769 $ 6,323 $ 713 $ (713 ) $ 6,323 (a) Includes gains (losses) on commodity derivatives.

Disposition (Tables)

Disposition (Tables)	12 Months Ended
	Dec. 31, 2018
Disposition Of Businesses [Abstract]
Schedule of Pre-tax Income (Loss) Associated with Interests Excluding Financial Statement Impacts Resulting from Asset Sales	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: 2018 2017 2016 (In millions) Equatorial Guinea (a) $ — $ 69 $ (95 ) Norway (b) — (55 ) (195 ) Income (Loss) from Continuing Operations Before Income Taxes $ — $ 14 $ (290 ) (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)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2018
Inventory Disclosure [Abstract]
Inventories	Inventories at December 31 were as follows: 2018 2017 (In millions) Crude oil and natural gas liquids $ 74 $ 59 Materials and supplies 171 173 Total Inventories $ 245 $ 232

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
Property Plant And Equipment [Abstract]
Components of Property, Plant and Equipment	Property, plant and equipment at December 31 were as follows: 2018 2017 (In millions) Exploration and Production Unproved properties $ 394 $ 520 Proved properties 3,124 3,162 Wells, equipment and related facilities 26,173 25,550 29,691 29,232 Midstream 3,492 3,219 Corporate and Other 39 53 Total — at cost 33,222 32,504 Less: Reserves for depreciation, depletion, amortization and lease impairment 17,139 16,312 Property, Plant and Equipment — Net $ 16,083 $ 16,192
Net Changes in Capitalized Exploratory Well Costs	Capitalized Exploratory Well Costs : The following table discloses the amount of capitalized exploratory well costs pending determination of proved reserves at December 31, and the changes therein during the respective years: 2018 2017 2016 (In millions) Balance at January 1 $ 304 $ 597 $ 1,415 Additions to capitalized exploratory well costs pending the determination of proved reserves 128 116 79 Reclassifications to wells, facilities and equipment based on the determination of proved reserves — (165 ) — Capitalized exploratory well costs charged to expense (14 ) (268 ) (897 ) Dispositions and other — 24 — Balance at December 31 $ 418 $ 304 $ 597 Number of Wells at December 31 24 12 17
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 $267 million at December 31, 2018, separated by year of completion as follows (in millions): 2017 $ 97 2016 — 2015 166 2014 — 2013 4 $ 267

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Components of Debt	Total debt at December 31 consisted of the following: 2018 2017 (In millions) Debt - Hess Corporation: Fixed-rate public notes: 8.1% due 2019 $ — $ 349 3.5% due 2024 298 297 4.3% due 2027 992 991 7.9% due 2029 463 500 7.3% due 2031 627 679 7.1% due 2033 537 596 6.0% due 2040 740 740 5.6% due 2041 1,234 1,234 5.8% due 2047 493 493 Total fixed-rate public notes 5,384 5,879 Capital lease obligations 269 — Financing obligations associated with floating production system 40 118 Fair value adjustments - interest rate hedging (2 ) — Total Debt - Hess Corporation $ 5,691 $ 5,997 Debt - Midstream: Fixed-rate notes: 5.6% due 2026 - HIP $ 787 $ 785 Term loan A facility - HIP 194 195 Total Debt - Midstream $ 981 $ 980 Total Debt: Current maturities of long-term debt $ 67 $ 580 Long-term debt 6,605 6,397 Total Debt $ 6,672 $ 6,977
Maturity Profile of Total Debt	At December 31, 2018, the maturity profile of total debt was as follows: Total Hess Corporation Midstream (In millions) 2019 $ 67 $ 56 $ 11 2020 32 17 15 2021 34 18 16 2022 171 19 152 2023 21 21 — Thereafter 6,347 5,560 787 Total debt (excluding interest) $ 6,672 $ 5,691 $ 981
Other Outstanding Letters of Credit	Other outstanding letters of credit at December 31 were as follows: 2018 2017 (In millions) Committed lines (a) $ 29 $ 29 Uncommitted lines (a) 255 217 Total $ 284 $ 246 (a) At December 31, 2018, committed and uncommitted lines have expiration dates throughout 2019.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Changes to and Maturity of Asset Retirement Obligations	The following table describes changes to and maturity of our asset retirement obligations: 2018 2017 (In millions) Balance at January 1 $ 801 $ 2,128 Liabilities incurred 68 62 Liabilities settled or disposed of (46 ) (1,464 ) Accretion expense 37 97 Revisions of estimated liabilities 1 (54 ) Foreign currency remeasurement (4 ) 32 Balance at December 31 $ 857 $ 801 Total Asset Retirement Obligations at December 31: Current portion of asset retirement obligations $ 116 $ 48 Long-term asset retirement obligations 741 753 Total at December 31 $ 857 $ 801

Retirement Plans (Tables)

Retirement Plans (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 2018 2017 (In millions) Change in Benefit Obligation Balance at January 1, $ 2,765 $ 2,560 $ 249 $ 256 $ 87 $ 84 Service cost 30 36 12 13 2 4 Interest cost 84 93 7 9 3 3 Actuarial (gains) loss (a) (237 ) 138 (29 ) 10 (24 ) 3 Benefit payments (b) (110 ) (113 ) (19 ) (39 ) (7 ) (7 ) Plan curtailments (10 ) (3 ) (4 ) — (2 ) — Plan amendments 4 — — — — — Foreign currency exchange rate changes (34 ) 54 — — — — Balance at December 31, (c) 2,492 2,765 216 249 59 87 Change in Fair Value of Plan Assets Balance at January 1, $ 2,732 $ 2,284 $ — $ — $ — $ — Actual return on plan assets (77 ) 351 — — — — Employer contributions 59 158 19 39 7 7 Benefit payments (b) (110 ) (113 ) (19 ) (39 ) (7 ) (7 ) Foreign currency exchange rate changes (36 ) 52 — — — — Balance at December 31, 2,568 2,732 — — — — Funded Status (Plan assets greater (less) than benefit obligations) at December 31, $ 76 $ (33 ) $ (216 ) $ (249 ) $ (59 ) $ (87 ) Unrecognized Net Actuarial (Gains) Losses $ 778 $ 789 $ 47 $ 84 $ (32 ) $ (10 ) (a) The change in discount rate in 2018 resulted in total actuarial gains of approximately $235 million (2017: $170 million of actuarial losses). (b) Benefit payments include lump-sum settlement payments of approximately $32 million in 2018 (2017: $57 million). (c) At December 31, 2018, the accumulated benefit obligation for the funded and unfunded defined benefit pension
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 2018 2017 2018 2017 2018 2017 (In millions) Noncurrent assets $ 76 $ 22 $ — $ — $ — $ — Current liabilities — — (30 ) (18 ) (9 ) (11 ) Noncurrent liabilities — (55 ) (186 ) (231 ) (50 ) (76 ) Pension assets / (accrued benefit liability) $ 76 $ (33 ) $ (216 ) $ (249 ) $ (59 ) $ (87 ) Accumulated other comprehensive loss, pre-tax (a) $ 778 $ 789 $ 47 $ 84 $ (32 ) $ (10 ) (a) The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $581 million at December 31, 2018 (2017: $548 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 2018 2017 2016 2018 2017 2016 (In millions) Service cost $ 42 $ 49 $ 60 $ 2 $ 4 $ 4 Interest cost 91 102 107 3 3 3 Expected return on plan assets (194 ) (168 ) (166 ) — — — Amortization of unrecognized net actuarial losses (gains) 39 58 60 (2 ) — — Settlement loss 4 19 — — — — Curtailment gain — — — (2 ) — — Special termination benefit recognized — — 1 — — — Net Periodic Benefit Cost (a) $ (18 ) $ 60 $ 62 $ 1 $ 7 $ 7
Actuarial Assumptions Used For Pension Plans & Postretirement Medical Plan	The weighted average actuarial assumptions used to determine Benefit obligations at December 31 and Net periodic benefit cost for the three years ended December 31 for our funded and unfunded pension plans were as follows: 2018 2017 2016 Benefit Obligations: Discount rate 3.9 % 3.3 % 3.7 % Rate of compensation increase 3.8 % 4.5 % 4.6 % Net Periodic Benefit Cost: Discount rate Service cost 3.9 % 3.7 % 4.1 % Interest cost 3.3 % 3.7 % 4.1 % Expected return on plan assets 7.2 % 7.3 % 7.4 % Rate of compensation increase 4.5 % 4.6 % 4.5 % The actuarial assumptions used to determine Benefit obligations at December 31 for the postretirement medical plan were as follows: 2018 2017 2016 Discount rate 3.9 % 3.2 % 3.5 % Initial health care trend rate 6.9 % 7.3 % 7.7 % 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	The following tables provide the fair value of the financial assets of the funded pension plans at December 31, 2018 and 2017 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 Net Asset Value (d) Total (In millions) December 31, 2018 Cash and Short-Term Investment Funds $ 3 $ 47 $ — $ — $ 50 Equities: U.S. equities (domestic) 654 — — — 654 International equities (non-U.S.) 92 29 — 288 409 Global equities (domestic and non-U.S.) 2 203 — — 205 Fixed Income: Treasury and government issued (a) — 240 — — 240 Government related (b) — 37 — — 37 Mortgage-backed securities (c) — 159 — 27 186 Corporate — 272 — 31 303 Other: Hedge funds — — — 135 135 Private equity funds — — — 170 170 Real estate funds 49 — 61 50 160 Diversified commodities funds — 19 — — 19 Total investments $ 800 $ 1,006 $ 61 $ 701 $ 2,568 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 34 — 296 434 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) — 139 1 26 166 Corporate — 182 — 6 188 Other: Hedge funds — — — 187 187 Private equity funds — — — 140 140 Real estate funds 63 — 2 92 157 Diversified commodities funds — 24 — — 24 Total investments $ 990 $ 991 $ 4 $ 747 $ 2,732 (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. (d) Includes certain investments that have been valued using the net asset value practical expedient, and therefore have not been categorized in the fair value hierarchy. The inclusion of such amounts in the above table is intended to aid reconciliation of investments categorized in the fair value hierarchy to total pension plan assets.
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: Fixed Real Estate Income Funds Total (In millions) Balance at January 1, 2017 $ 2 $ 8 $ 10 Actual return on plan assets — — — Purchases, sales or other settlements 1 (6 ) (5 ) Net transfers in (out) of Level 3 (1 ) — (1 ) Balance at December 31, 2017 2 2 4 Actual return on plan assets — 1 1 Purchases, sales or other settlements (2 ) 58 56 Net transfers in (out) of Level 3 — — — Balance at December 31, 2018 $ — $ 61 $ 61
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): 2019 $ 142 2020 139 2021 135 2022 139 2023 140 Years 2024 to 2028 722

Share-based Compensation (Table

Share-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2018
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-based Compensation Activity	S hare‑based compensation expense consisted of the following: 2018 2017 2016 (In millions) Restricted stock $ 40 $ 56 $ 45 Stock options 10 9 7 Performance share units 22 21 21 Share-based compensation expense before income taxes $ 72 $ 86 $ 73 Income tax benefit on share-based compensation expense $ — $ 1 $ 28
Summary of Restricted Stock Award Activity	The following is a summary of restricted stock award activity in 2018: Shares of Restricted Common Stock Weighted - Average Price on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2018 3,202 $ 54.04 Granted 1,258 50.78 Vested (a) (1,099 ) 65.80 Forfeited (480 ) 50.63 Outstanding at December 31, 2018 2,881 $ 48.70
Summary of PSU Activity	The following is a summary of PSU activity in 2018: Performance Share Units Weighted - Average Fair Value on Date of Grant (In thousands, except per share amounts) Outstanding at January 1, 2018 1,146 $ 58.78 Granted 278 59.65 Vested (a) (313 ) 76.64 Forfeited (48 ) 53.62 Outstanding at December 31, 2018 1,063 $ 53.98
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: 2018 2017 2016 Risk free interest rate 2.39 % 1.55 % 0.96 % Stock price volatility 0.400 0.387 0.329 Contractual term in years 3.0 3.0 3.0 Grant date price of Hess common stock $ 48.48 $ 51.03 $ 44.31
Summary of Stock Option Activity	The following is a summary of stock options activity in 2018: Number of options (In thousands) Weighted Average Exercise Price per Share Weighted Average Remaining Contractual Term Outstanding at January 1, 2018 6,482 $ 66.84 3.6 years Granted 683 48.48 Exercised (564 ) 55.84 Forfeited (1,431 ) 80.23 Outstanding at December 31, 2018 5,170 $ 61.91 4.3 years
Weighted Average Assumptions Utilized to Estimate Fair Value of Stock Options	At December 31, 2018, there were 5.2 million outstanding stock options (3.9 million exercisable) with a weighted average remaining contractual life of 4.3 years (2.9 years for exercisable options) and an aggregated intrinsic value of 0 (0 for exercisable options). The following weighted average assumptions were utilized to estimate the fair value of stock options: 2018 2017 2016 Risk free interest rate 2.74 % 2.17 % 1.47 % Stock price volatility 0.322 0.333 0.326 Dividend yield 2.06 % 1.96 % 2.26 % Expected life in years 6.0 6.0 6.0 Weighted average fair value per option granted $ 13.69 $ 14.51 $ 11.33

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Components of Income Tax Provision (Benefit)	The provision (benefit) for income taxes consisted of: 2018 2017 2016 (a) (In millions) United States Federal Current $ 1 $ (23 ) $ (27 ) Deferred taxes and other accruals (74 ) (6 ) 1,948 State (45 ) — 23 (118 ) (29 ) 1,944 Foreign Current (b) 455 179 36 Deferred taxes and other accruals (2 ) (1,987 ) 235 453 (1,808 ) 271 Total 335 (1,837 ) 2,215 Adjustment of deferred taxes for foreign income tax law changes — — 7 Total Provision (Benefit) For Income Taxes $ 335 $ (1,837 ) $ 2,222 (a) Includes charges of $3,749 million to establish valuation allowances on net deferred tax assets. (b) Primarily comprised of Libya in 2018 and 2017.
Income (Loss) Before Income Taxes	Income (loss) before income taxes consisted of the following: 2018 2017 2016 (In millions) United States (a) $ (219 ) $ (2,784 ) $ (2,431 ) Foreign 439 (2,994 ) (1,423 ) Total Income (Loss) Before Income Taxes $ 220 $ (5,778 ) $ (3,854 ) (a) Includes substantially all of our interest expense, corporate expense and the results of commodity hedging activities.
Effective Income Tax Rate Reconciliation	The difference between our effective income tax rate and the U.S. statutory rate is reconciled below: 2018 2017 2016 U.S. statutory rate 21.0 % 35.0 % 35.0 % Effect of foreign operations (a) 141.2 17.4 4.6 State income taxes, net of Federal income tax (18.9 ) — 1.9 Change in enacted tax laws (b) — (23.6 ) (0.2 ) Valuation allowance adjustment with tax law change (b) — 23.6 — Rate differential on U.S. loss — (4.1 ) — Gains on asset sales, net — (2.2 ) — Impairment — — (2.1 ) Valuation allowance on current year operations 55.2 (14.9 ) — Valuation allowance against previously benefitted deferred tax assets — 0.1 (97.3 ) Noncontrolling interest in partnership (15.9 ) 0.8 0.5 Intraperiod allocation (37.3 ) — — Equity compensation shortfall 6.3 (0.3 ) — Other 0.8 — (0.1 ) Total 152.4 % 31.8 % (57.7 ) % (a) The variance in effective income tax rates attributable to the effect of foreign operations primarily resulted from the mix of income among high, primarily Libya, 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 $1,336 million reduction to our U.S. net deferred tax asset at December 31, 2017, with a corresponding reduction in the previously established U.S. valuation allowance.
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: 2018 2017 (In millions) Deferred Tax Liabilities Property, plant and equipment and investments $ (853 ) $ (629 ) Other (77 ) (24 ) Total Deferred Tax Liabilities (930 ) (653 ) Deferred Tax Assets Net operating loss carryforwards 4,239 4,029 Tax credit carryforwards 134 138 Property, plant and equipment and investments 416 746 Accrued compensation, deferred credits and other liabilities 232 283 Asset retirement obligations 225 212 Other 161 36 Total Deferred Tax Assets 5,407 5,444 Valuation allowances (a) (4,877 ) (5,199 ) Total deferred tax assets, net of valuation allowances 530 245 Net Deferred Tax Assets (Liabilities) $ (400 ) $ (408 ) (a) In 2018, the valuation allowance decreased by $322 million (2017: decrease of $251 million; 2016: increase of $3,872). In the Consolidated Balance Sheet 2018 2017 (In millions) Deferred income taxes (long-term asset) $ 21 $ 21 Deferred income taxes (long-term liability) (421 ) (429 ) Net Deferred Tax Assets (Liabilities) $ (400 ) $ (408 )
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: 2018 2017 2016 (In millions) Balance at January 1 $ 205 $ 424 $ 604 Additions based on tax positions taken in the current year 19 14 19 Additions based on tax positions of prior years 36 4 113 Reductions based on tax positions of prior years (78 ) (147 ) (274 ) Reductions due to settlements with taxing authorities (10 ) (85 ) (27 ) Reductions due to lapses in statutes of limitation (4 ) (5 ) (11 ) Balance at December 31 $ 168 $ 205 $ 424

Basic and Diluted Earnings Pe_2

Basic and Diluted Earnings Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Net Income (Loss) and Weighted Average Number of Common Shares Used in Computation of Basic and Diluted Earnings Per Share	The Net income (loss) and weighted average number of common shares used in basic and diluted earnings per share computation were as follows: 2018 2017 2016 (In millions) Net Income (Loss) Attributable to Hess Corporation Common Stockholders: Net income (loss) $ (115 ) $ (3,941 ) $ (6,076 ) Less: Net income (loss) attributable to noncontrolling interests 167 133 56 Less: Preferred stock dividends 46 46 41 Net income (loss) attributable to Hess Corporation Common Stockholders $ (328 ) $ (4,120 ) $ (6,173 ) Weighted Average Number of Common Shares Outstanding: Basic 298.2 314.1 309.9 Effect of dilutive securities Restricted common stock — — — Stock options — — — Performance share units — — — Mandatory Convertible Preferred stock — — — Diluted 298.2 314.1 309.9 Net Income (Loss) Attributable to Hess Corporation per Common Share: Basic $ (1.10 ) $ (13.12 ) $ (19.92 ) Diluted $ (1.10 ) $ (13.12 ) $ (19.92 ) Antidilutive shares excluded from the computation of diluted shares: Restricted common stock 2.9 3.3 3.3 Stock options 5.5 6.4 6.9 Performance share units 1.1 0.6 0.9 Common shares from conversion of preferred stock 12.7 12.8 11.2

Common and Preferred Stock (Tab

Common and Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2018
Stockholders Equity Note [Abstract]
Changes in Outstanding Common Shares	The following table provides the changes in our outstanding common shares: 2018 2017 2016 (In millions) Balance at January 1 315.1 316.5 286.0 Shares issued — — 28.8 Activity related to restricted stock awards, net 0.8 0.8 1.1 Stock options exercised 0.6 0.2 0.2 PSU vested 0.1 0.2 0.4 Shares repurchased (25.2 ) (2.6 ) — Balance at December 31 291.4 315.1 316.5

Supplementary Cash Flow Infor_2

Supplementary Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 (In millions) Cash Flows from Operating Activities Interest paid $ (394 ) $ (314 ) $ (338 ) Net income taxes (paid) refunded (463 ) (210 ) 132 Cash Flows from Investing Activities Capital expenditures incurred - E&P $ (1,909 ) $ (1,852 ) $ (1,638 ) Increase (decrease) in related liabilities 55 64 (336 ) Additions to property, plant and equipment - E&P $ (1,854 ) $ (1,788 ) $ (1,974 ) Capital expenditures incurred - Midstream $ (271 ) $ (121 ) $ (283 ) Increase (decrease) in related liabilities 28 (28 ) 6 Additions to property, plant and equipment - Midstream $ (243 ) $ (149 ) $ (277 )

Leased Assets (Tables)

Leased Assets (Tables)	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
Future Minimum Rental Payments	At December 31, 2018, future minimum rental payments applicable to non‑cancelable operating leases with remaining terms in excess of one year (other than oil and gas property leases) are as follows (in millions): 2019 $ 355 2020 156 2021 65 2022 64 2023 64 Remaining years 198 Total Minimum Lease Payments 902 Less: Income from subleases 114 Net Minimum Lease Payments $ 788
Rental Expense	Rental expense was as follows: 2018 2017 2016 (In millions) Total rental expense $ 154 $ 123 $ 106 Less: Income from subleases 8 10 5 Net Rental Expense $ 146 $ 113 $ 101

Guarantees, Contingencies and_2

Guarantees, Contingencies and Commitments (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments And Contingencies Disclosure [Abstract]
Schedule of Unconditional Purchase Obligations and Commitments	The following table shows aggregate information for certain unconditional purchase obligations and commitments at December 31, 2018, which are not included elsewhere within these Consolidated Financial Statements Payments Due by Period 2020 and 2022 and Total 2019 2021 2023 Thereafter (In millions) Capital expenditures $ 1,069 $ 443 $ 551 $ 75 $ — Operating expenses 433 219 99 61 54 Transportation and related contracts 1,050 212 401 336 101

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Financial Data by Operating Segment	The following table presents operating segment financial data (in millions): Exploration and Production Midstream Corporate, Interest and Other Eliminations Total 2018 Sales and Other Operating Revenues - Third-parties $ 6,323 $ — $ — $ — $ 6,323 Intersegment Revenues — 713 — (713 ) — Sales and Other Operating Revenues $ 6,323 $ 713 $ — $ (713 ) $ 6,323 Net Income (Loss) Attributable to Hess Corporation $ 51 $ 120 $ (453 ) $ — $ (282 ) Interest Expense — 60 339 — 399 Depreciation, Depletion and Amortization 1,748 127 8 — 1,883 Provision (Benefit) for Income Taxes (a) 391 38 (94 ) — 335 Investment in Affiliates 126 67 — — 193 Identifiable Assets 16,109 3,285 2,039 — 21,433 Capital Expenditures 1,909 271 — — 2,180 2017 Sales and Other Operating Revenues - Third-parties $ 5,460 $ 6 $ — $ — $ 5,466 Intersegment Revenues — 611 — (611 ) — Sales and Other Operating Revenues $ 5,460 $ 617 $ — $ (611 ) $ 5,466 Net Income (Loss) 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 Sales and Other Operating Revenues - Third-parties $ 4,755 $ 7 $ — $ — $ 4,762 Intersegment Revenues — 562 — (562 ) — Sales and Other Operating Revenues $ 4,755 $ 569 $ — $ (562 ) $ 4,762 Net Income (Loss) 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 Capital Expenditures 1,638 283 — — 1,921 (a) The provision for income taxes in the Midstream segment in 2018 and 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) 2018 Sales and Other Operating Revenues $ 4,842 $ 164 $ 548 $ 769 $ — $ 6,323 Net Income (Loss) Attributable to Hess Corporation 131 42 36 (38 ) (453 ) (282 ) Depreciation, Depletion and Amortization 1,424 37 19 395 8 1,883 Provision (Benefit) for Income Taxes (25 ) 15 430 9 (94 ) 335 Identifiable Assets 13,250 1,033 395 4,716 2,039 21,433 Property, Plant and Equipment (Net) 11,653 906 355 3,154 15 16,083 Capital Expenditures 1,543 8 9 620 — 2,180 2017 Sales and Other Operating Revenues $ 3,692 $ 629 $ 675 $ 470 $ — $ 5,466 Net Income (Loss) 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 Sales and Other Operating Revenues $ 3,085 $ 610 $ 601 $ 466 $ — $ 4,762 Net Income (Loss) 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 Capital Expenditures 1,400 59 10 452 — 1,921

Financial Risk Management Act_2

Financial Risk Management Activities (Tables)	12 Months Ended
	Dec. 31, 2018
Derivative Instruments Gain Loss [Line Items]
Gross and Net Fair Values of Financial Risk Management Derivative Instruments	The table below reflects the gross and net fair values of risk management derivative instruments and their respective financial statement caption in the Consolidated Balance Sheet Assets Liabilities (In millions) December 31, 2018 Derivative Contracts Designated as Hedging Instruments Commodity - Other current assets $ 484 $ — Interest rate - Other liabilities and deferred credits (noncurrent) — (2 ) Total derivative contracts designated as hedging instruments 484 (2 ) Gross fair value of derivative contracts 484 (2 ) Master netting arrangements — — Net Fair Value of Derivative Contracts $ 484 $ (2 ) 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 - Accounts receivable: Joint venture and other 1 — Total derivative contracts not designated as hedging instruments 1 (2 ) Gross fair value of derivative contracts 1 (13 ) Master netting arrangements — — Net Fair Value of Derivative Contracts $ 1 $ (13 )
Related to West Texas Intermediate (WTI) Instruments
Derivative Instruments Gain Loss [Line Items]
Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts	The gross notional amounts of outstanding financial risk management derivative contracts related to WTI instruments as of the dates shown below were as follows: December 31, 2018 December 31, 2017 Calendar year program 2019 2018 Instrument type Puts Collars Crude oil volumes (millions of barrels) 34.7 42.0 Ceiling price N/A $ 65 Floor price $ 60 $ 50
Excluding West Texas Intermediate (WTI)
Derivative Instruments Gain Loss [Line Items]
Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts	The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows: December 31, 2018 December 31, 2017 (In millions) Foreign exchange $ 16 $ 52 Interest rate swaps $ 100 $ 450

Nature of Operations, Basis o_3

Nature of Operations, Basis of Presentation and Summary of Accounting Policies - Additional Information (Detail) $ in Millions	Jan. 01, 2019USD ($)	Dec. 31, 2018USD ($)Project	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Oct. 01, 2018USD ($)
Basis of Presentation and Principles of Consolidation [Abstract]
Number of exploration projects in which the entity has participating interest | Project		12
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Reclassification of net expense to other, net from operating costs and expenses, and general and administrative expenses			$ 14	$ 5
Cumulative effect of hedging ineffectiveness			0	(37)
Goodwill		$ 360	360
Environmental Property Sale, Disposal or Abandonment Costs [Abstract]
Reserve for estimated remediation liabilities		80
Midstream
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Goodwill		360
Retained Earnings
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness			101	(39)
Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness			$ (101)	$ 0
ASU 2017-12 | Retained Earnings
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness		1
ASU 2017-12 | Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness		(1)
Adoption of ASU 2018-02 | Retained Earnings
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness					$ 100
Adoption of ASU 2018-02 | Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Cumulative effect of hedging ineffectiveness					$ (100)
ASC 842
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Operating and finance lease obligations		$ 390
ASC 842 | Subsequent Event
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Operating and finance lease obligations	$ 1,200
Variable Interest Entity, Primary Beneficiary | Hess Infrastructure Partners LP (HIP)
Basis of Presentation and Principles of Consolidation [Abstract]
Variable interest in Hess Infrastructure Partners LP (HIP)		50.00%
Minimum
Basis of Presentation and Principles of Consolidation [Abstract]
Percentage of voting interest owned in entities consolidated in the financial statements		50.00%
Minimum | Affiliated Companies
Basis of Presentation and Principles of Consolidation [Abstract]
Equity method investment, ownership percentage		20.00%
Maximum
Defined Benefit Plan, Funded Status of Plan [Abstract]
Percentage of actuarial gains and losses in excess of greater of benefit obligation		10.00%
Maximum | Affiliated Companies
Basis of Presentation and Principles of Consolidation [Abstract]
Equity method investment, ownership percentage		50.00%
Stabroek Block
Basis of Presentation and Principles of Consolidation [Abstract]
Project participation interest percentage		30.00%

Revenue - Summary of Revenue fr

Revenue - Summary of Revenue from Contracts with Customers on a Disaggregated Basis (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	$ 6,458
Other operating revenues (a)	(135)
Total sales and other operating revenues	6,323	$ 5,466	$ 4,762
United States
Disaggregation Of Revenue [Line Items]
Total sales and other operating revenues	4,842	3,692	3,085
Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	3,523
Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	308
Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	859
Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	1,768
Operating Segments | Europe
Disaggregation Of Revenue [Line Items]
Total sales and other operating revenues	164	629	610
Operating Segments | Africa
Disaggregation Of Revenue [Line Items]
Total sales and other operating revenues	548	675	601
Operating Segments | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	6,458
Other operating revenues (a)	(135)
Total sales and other operating revenues	6,323	5,460	4,755
Operating Segments | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	4,977
Other operating revenues (a)	(135)
Total sales and other operating revenues	4,842
Operating Segments | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	164
Other operating revenues (a)	0
Total sales and other operating revenues	164
Operating Segments | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	548
Other operating revenues (a)	0
Total sales and other operating revenues	548
Operating Segments | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	769
Other operating revenues (a)	0
Total sales and other operating revenues	769
Operating Segments | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	713
Other operating revenues (a)	0
Total sales and other operating revenues	713	617	569
Operating Segments | Intercompany Revenue | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Intercompany Revenue | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Intercompany Revenue | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Intercompany Revenue | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Intercompany Revenue | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Intercompany Revenue | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	713
Operating Segments | Crude Oil Revenue | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	3,523
Operating Segments | Crude Oil Revenue | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	2,832
Operating Segments | Crude Oil Revenue | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	153
Operating Segments | Crude Oil Revenue | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	434
Operating Segments | Crude Oil Revenue | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	104
Operating Segments | Crude Oil Revenue | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Natural Gas Liquids Revenue | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	308
Operating Segments | Natural Gas Liquids Revenue | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	308
Operating Segments | Natural Gas Liquids Revenue | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Natural Gas Liquids Revenue | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Natural Gas Liquids Revenue | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Natural Gas Liquids Revenue | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Natural Gas Revenue | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	859
Operating Segments | Natural Gas Revenue | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	176
Operating Segments | Natural Gas Revenue | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	11
Operating Segments | Natural Gas Revenue | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	21
Operating Segments | Natural Gas Revenue | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	651
Operating Segments | Natural Gas Revenue | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Sales of Purchased Oil and Gas | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	1,768
Operating Segments | Sales of Purchased Oil and Gas | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	1,661
Operating Segments | Sales of Purchased Oil and Gas | Exploration and Production | Europe
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Operating Segments | Sales of Purchased Oil and Gas | Exploration and Production | Africa
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	93
Operating Segments | Sales of Purchased Oil and Gas | Exploration and Production | Asia
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	14
Operating Segments | Sales of Purchased Oil and Gas | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Eliminations
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	(713)
Other operating revenues (a)	0
Total sales and other operating revenues	(713)	$ (611)	$ (562)
Eliminations | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	(713)
Eliminations | Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Eliminations | Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Eliminations | Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0
Eliminations | Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	$ 0

Revenue - Additional Informatio

Revenue - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
Exploration and Production
Disaggregation Of Revenue [Line Items]
Contract assets	$ 0	$ 0	$ 0
Contract Liability	0	$ 0	$ 0
Impairment losses on receivables arising from contracts with customers	$ 0
Midstream
Disaggregation Of Revenue [Line Items]
Initial revenue contract period		10 years
Additional revenue contract period		10 years

Dispositions - Additional Infor

Dispositions - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales	$ 607	$ 3,296	$ 140
Gain (loss) on asset sales, pre-tax	32	(86)	23
Loss included recognition earnings for cumulative translation adjustments	0	900	0
Miscellaneous Non-core Assets
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales		194	100
Gain (loss) on asset sales, pre-tax		12	23
Gain (loss) on asset sale, after-tax		12	$ 14
Ghana
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Agreement entered to sell interest, total consideration	100
Gain (loss) on asset sales, pre-tax	10
Gain (loss) on asset sale, after-tax	10
Payment upon closing | Ghana
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales	25
Payable upon approval of the Plan of Development | Ghana
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Agreement entered to sell interest, total consideration	75
Utica Shale Play, Eastern Ohio | Eastern Ohio
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales	396
Gain (loss) on asset sales, pre-tax	14
Gain (loss) on asset sale, after-tax	$ 14
Permian Basin
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales		597
Gain (loss) on asset sales, pre-tax		273
Gain (loss) on asset sale, after-tax		280
Permian Basin | Exploration and Production
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain (loss) on asset sale, after-tax		314
Permian Basin | Midstream
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain (loss) on asset sale, after-tax		(34)
Equatorial Guinea
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales		449
Gain (loss) on asset sales, pre-tax		486
Gain (loss) on asset sale, after-tax		486
Offshore Norway
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales		2,056
Gain (loss) on asset sales, pre-tax		(857)
Gain (loss) on asset sale, after-tax		$ (857)

Dispositions - Schedule of Pre-

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, 2018	Dec. 31, 2017	Dec. 31, 2016
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	$ 220	$ (5,778)	$ (3,854)
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	0	14	(290)
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	0	69	(95)
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	$ 0	$ (55)	$ (195)

Dispositions - Schedule of Pr_2

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		3 Months Ended	12 Months Ended
	Dec. 31, 2017	Nov. 30, 2017	Sep. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disposition Of Businesses [Line Items]
Impairment				$ 0	$ 4,203	$ 67
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

Inventories - Inventories (Deta

Inventories - Inventories (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 74	$ 59
Materials and supplies	171	173
Total Inventories	$ 245	$ 232

Property, Plant and Equipment -

Property, Plant and Equipment - Components of Property, Plant and Equipment (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Property Plant And Equipment [Line Items]
Total — at cost	$ 33,222	$ 32,504
Less: Reserves for depreciation, depletion, amortization and lease impairment	17,139	16,312
Property, plant and equipment — net	16,083	16,192
Exploration and Production
Property Plant And Equipment [Line Items]
Unproved properties	394	520
Proved properties	3,124	3,162
Wells, equipment and related facilities	26,173	25,550
Total — at cost	29,691	29,232
Midstream
Property Plant And Equipment [Line Items]
Total — at cost	3,492	3,219
Corporate and Other
Property Plant And Equipment [Line Items]
Total — at cost	$ 39	$ 53

Property, Plant and Equipment_2

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)Well	Dec. 31, 2017USD ($)Well	Dec. 31, 2016USD ($)Well
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 304	$ 597	$ 1,415
Additions to capitalized exploratory well costs pending the determination of proved reserves	128	116	79
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	0	(165)	0
Capitalized exploratory well costs charged to expense	(14)	(268)	(897)
Dispositions and other	0	24	0
Ending balance	$ 418	$ 304	$ 597
Number of Wells at December 31 | Well	24	12	17

Property, Plant and Equipment_3

Property, Plant and Equipment - Additional Information (Detail) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017USD ($)	Jun. 30, 2016Well	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Capitalized Exploratory Well Costs [Line Items]
Charge to write-off previously capitalized exploratory wells			$ 14	$ 268	$ 897
Exploratory dry hole costs which were incurred and subsequently expensed			151	$ 0	167
Capitalized exploratory well costs that have been capitalized for period greater than one year			$ 267
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 participation interest percentage			28.00%
Capitalized well costs percentage			45.00%
Liza-4, Payara-1, Payara-2 and Snoek-1 Wells on the Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage			30.00%
Capitalized well costs percentage			35.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage			50.00%
Capitalized well costs percentage			15.00%
North Malay Basin, offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage			50.00%
Capitalized well costs percentage			5.00%
Canada
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage			50.00%
Charge to write-off previously capitalized exploratory wells			$ 120
Exploratory dry hole costs which were incurred and expensed			$ 106
Ghana
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage	50.00%			50.00%
Charge to write-off previously capitalized exploratory wells	$ 268			$ 268

Property, Plant and Equipment_4

Property, Plant and Equipment - Exploratory Drilling Costs Capitalized (Detail) $ in Millions	Dec. 31, 2018USD ($)
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	$ 267
Year 2,017
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	97
Year 2,016
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 2,015
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	166
Year 2,014
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	0
Year 2,013
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 4

Hess Infrastructure Partners _2

Hess Infrastructure Partners LP - Additional Information (Detail) - USD ($) $ in Millions	Jul. 01, 2015	Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Apr. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Variable Interest Entity [Line Items]
Percentage interest sold of Hess Infrastructure Partners (HIP)	50.00%
Proceeds from sale of interest in Hess Infrastructure Partners (HIP)	$ 2,600
Term of tariff agreements between E&P operating segment & Midstream entities			10 years
Additional renewal period of tariff agreements by Midstream			10 years
Cash and cash equivalents		$ 2,694	$ 2,694	$ 4,847		$ 2,732	$ 2,716
Property, plant and equipment, net		$ 16,083	$ 16,083	16,192
Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Noncontrolling interest ownership percentage in Hess Infrastructure Partners LP (HIP) by Global Infrastructure Partners (GIP)		50.00%	50.00%		50.00%
Variable Interest Entity, Primary Beneficiary | Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Ownership percentage in Hess Infrastructure Partners LP (HIP) by Hess Corporation		50.00%
Cash and cash equivalents		$ 109	$ 109	356
Property, plant and equipment, net		2,664	2,664	2,520
HIP's liabilities on a nonrecourse to Hess Corporation		$ 1,105	$ 1,105	$ 1,065
Global Infrastructure Partners (GIP) | Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Noncontrolling interest ownership percentage in Hess Infrastructure Partners LP (HIP) by Global Infrastructure Partners (GIP)		50.00%	50.00%

Hess Midstream Partners LP - _2

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, 2018
Hess Infrastructure Partners LP (HIP)
Limited Partners' Capital Account [Line Items]
Noncontrolling interest, ownership percentage	50.00%	50.00%
Public Unit Holders | Hess Midstream Partners LP
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]
Percentage of indirect ownership interest		a 50% indirect ownership interest through HIP
Global Infrastructure Partners (GIP) | Hess Midstream Partners LP
Limited Partners' Capital Account [Line Items]
Percentage of ownership interest in Partnership	33.75%	33.75%
Hess Corporation
Limited Partners' Capital Account [Line Items]
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 Corporation | Hess Midstream Partners LP
Limited Partners' Capital Account [Line Items]
Percentage of ownership interest in Partnership	33.75%	33.75%
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
Partnership controlling interest in operating companies, percentage	20.00%	20.00%

Debt - Other Outstanding Letter

Debt - Other Outstanding Letters of Credit (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 284	$ 246
Committed and Uncommitted Lines
Line Of Credit Facility [Line Items]
Maturity year	2,019

Debt - Components of Debt (Deta

Debt - Components of Debt (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total debt	$ 6,672	$ 6,977
Current maturities of long-term debt	67	580
Long-term debt	6,605	6,397
Midstream
Debt Instrument [Line Items]
Total debt	981	980
Midstream | Hess Infrastructure Partners
Debt Instrument [Line Items]
Term loan A facility	194	195
Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	5,384	5,879
Capital lease obligations	269	0
Financing obligations associated with floating production system	40	118
Total debt	5,691	5,997
Hess Corporation | Interest Rate Contract
Debt Instrument [Line Items]
Fair value adjustments - interest rate hedging	(2)	0
8.1% Due 2019 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	0	349
3.5% Due 2024 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	298	297
4.3% due 2027 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	992	991
7.9% Due 2029 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	463	500
7.3% Due 2031 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	627	679
7.1% Due 2033 | Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	537	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	1,234
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	$ 787	$ 785

Debt - Components of Debt (Pare

Debt - Components of Debt (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2018
8.1% Due 2019
Debt Instrument [Line Items]
Coupon rate	8.10%
Maturity year	2,019
3.5% Due 2024
Debt Instrument [Line Items]
Coupon rate	3.50%
Maturity year	2,024
4.3% due 2027
Debt Instrument [Line Items]
Coupon rate	4.30%
Maturity year	2,027
7.9% Due 2029
Debt Instrument [Line Items]
Coupon rate	7.90%
Maturity year	2,029
7.3% Due 2031
Debt Instrument [Line Items]
Coupon rate	7.30%
Maturity year	2,031
7.1% Due 2033
Debt Instrument [Line Items]
Coupon rate	7.10%
Maturity year	2,033
6.0% Due 2040
Debt Instrument [Line Items]
Coupon rate	6.00%
Maturity year	2,040
5.6% Due 2041
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2,041
5.8% Due 2047
Debt Instrument [Line Items]
Coupon rate	5.80%
Maturity year	2,047
5.6% Due 2026
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2,026

Debt - Maturity Profile of Tota

Debt - Maturity Profile of Total Debt (Detail) $ in Millions	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
2,019	$ 67
2,020	32
2,021	34
2,022	171
2,023	21
Thereafter	6,347
Total debt (excluding interest)	6,672
Midstream
Debt Instrument [Line Items]
2,019	11
2,020	15
2,021	16
2,022	152
2,023	0
Thereafter	787
Total debt (excluding interest)	981
Hess Corporation
Debt Instrument [Line Items]
2,019	56
2,020	17
2,021	18
2,022	19
2,023	21
Thereafter	5,560
Total debt (excluding interest)	$ 5,691

Debt - Additional Information (

Debt - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Nov. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Fixed-rate notes, gross principal amount		$ 5,438,000,000	$ 5,938,000,000
Weighted average interest rate - Hess Corp public notes		5.90%	6.00%
Additional secured debt allowed to be borrowed		$ 3,098,000,000
Capitalized interest		20,000,000	$ 86,000,000	$ 61,000,000
Debt instrument redemption amount		$ 553,000,000
Terminated interest rate swaps		terminated interest rate swaps with a notional amount of $350 million
Amount of terminated interest rate swaps		$ 350,000,000
Loss on debt extinguishment		53,000,000	0	148,000,000
Proceeds from asset sales		607,000,000	3,296,000,000	140,000,000
Letters of credit – Issued		284,000,000	$ 246,000,000
Midstream
Debt Instrument [Line Items]
Revolving credit facility - Capacity	$ 600,000,000			$ 400,000,000
Revolving credit facility expiration date	Nov. 30, 2022
Term Loan A facility - Term	5 years
Borrowings - Term Loan A	$ 200,000,000	$ 197,500,000
Revolving credit facility - Term	5 years
Leverage ratio - Maximum	500.00%
Secured leverage ratio - Maximum	375.00%
Midstream | Minimum
Debt Instrument [Line Items]
Interest coverage ratio - Minimum		225.00%
London Interbank Offered Rate (LIBOR) | Midstream | Minimum
Debt Instrument [Line Items]
Interest rate applicable margin	1.55%
London Interbank Offered Rate (LIBOR) | Midstream | Maximum
Debt Instrument [Line Items]
Interest rate applicable margin	2.50%
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility - Capacity		$ 4,000,000,000
Revolving credit facility 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 the 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
Letters of credit – Issued		0
Revolving Credit Facility | Hess Midstream Partners LP
Debt Instrument [Line Items]
Revolving credit facility - Capacity		$ 300,000,000
Revolving credit facility - Term		4 years
Leverage ratio - Maximum		450.00%
Revolving Credit Facility | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Interest rate applicable margin		1.30%
Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Hess Midstream Partners LP
Debt Instrument [Line Items]
Interest rate applicable margin		1.275%
Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Midstream | Minimum
Debt Instrument [Line Items]
Interest rate applicable margin	1.275%
Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Midstream | Maximum
Debt Instrument [Line Items]
Interest rate applicable margin	2.00%
Floating, Storage and Offloading Vessel
Debt Instrument [Line Items]
North Malay Basin, offshore Peninsular Malaysia - Hess operated interest		50.00%
Proceeds from asset sales		$ 260,000,000
Lease description		The lease agreement is for 16 years with four consecutive twelve-month renewal options that may be exercised at our discretion.
Carrying value of lease asset		$ 264,000,000
Capital leases carrying value		$ 269,000,000
Ratio of present value of future minimum lease payments to carrying value of lease obligation		100.00%
Capital lease obligation included in current maturities of long-term debt		$ 15,000,000
Capital lease obligation included in long-term debt		254,000,000
Gain or loss on sale of transaction		0
8.125% Notes Due 2019
Debt Instrument [Line Items]
Debt instrument redemption of principal amount		$ 350,000,000
Debt instrument interest rate		8.125%
Debt instrument maturity year		2,019
Carrying value of purchased debt		$ 150,000,000
Commitments Available for Final Year | Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility - Capacity		$ 3,700,000,000
5.625% Senior Notes Due in 2026 | Midstream
Debt Instrument [Line Items]
Debt instrument interest rate	5.625%
Unsecured debt issued	$ 800,000,000
Debt instrument maturity year	2026-02

Debt - Other Outstanding Lett_2

Debt - Other Outstanding Letters of Credit (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 284	$ 246
Committed Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	29	29
Uncommitted Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 255	$ 217

Asset Retirement Obligations -

Asset Retirement Obligations - Changes to and Maturity of Asset Retirement Obligations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 801	$ 2,128
Liabilities incurred	68	62
Liabilities settled or disposed of	(46)	(1,464)
Accretion expense	37	97
Revisions of estimated liabilities	1	(54)
Foreign currency remeasurement	(4)	32
Asset retirement obligations at end of period	857	801
Current portion of asset retirement obligations	116	48
Long-term asset retirement obligations	$ 741	$ 753

Asset Retirement Obligations _2

Asset Retirement Obligations - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations, related to participating interests	$ 25
Fair value of sinking fund deposits legally restricted for purposes of settling asset retirement obligations	$ 148	$ 118

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
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.
Curtailment gains included in accumulated other comprehensive income (loss)	$ 14
Budgeted contributions to funded pension plans for next year			$ 40
Expense for defined contribution plans			$ 19	$ 22	$ 25
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			30.00%
Other Types of Investments
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets			20.00%
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Curtailment gain			$ 2	0	0
Service costs			2	4	4
Interest costs			3	3	3
Amortization of unrecognized net actuarial losses			(2)	0	0
Expected return on plan assets			$ 0	$ 0	$ 0
United States
Defined Benefit Plan Disclosure [Line Items]
Decrease in post retirement liabilities	$ (125)
Scenario Forecast
Defined Benefit Plan Disclosure [Line Items]
Service costs		$ 40
Net non-service pension costs		40
Interest costs		95
Amortization of unrecognized net actuarial losses		45
Expected return on plan assets		$ 180

Retirement Plans - Change in Be

Retirement Plans - Change in Benefit Obligation, Fair Value of Plan Assets, and Funded Status of Pension Plans and Postretirement Medical Plan (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Change in Fair Value of Plan Assets
Beginning balance	$ 2,732
Ending balance	2,568	$ 2,732
Funded Pension Plans
Change in Benefit Obligation
Beginning balance	2,765	2,560
Service cost	30	36
Interest cost	84	93
Actuarial (gains) loss	(237)	138
Benefit payments	(110)	(113)
Plan curtailments	(10)	(3)
Plan amendments	4	0
Foreign currency exchange rate changes	(34)	54
Ending balance	2,492	2,765	$ 2,560
Change in Fair Value of Plan Assets
Beginning balance	2,732	2,284
Actual return on plan assets	(77)	351
Employer contributions	59	158
Benefit payments	(110)	(113)
Foreign currency exchange rate changes	(36)	52
Ending balance	2,568	2,732	2,284
Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	76	(33)
Unrecognized Net Actuarial (Gains) Losses	778	789
Postretirement Medical Plan
Change in Benefit Obligation
Beginning balance	87	84
Service cost	2	4	4
Interest cost	3	3	3
Actuarial (gains) loss	(24)	3
Benefit payments	(7)	(7)
Plan curtailments	(2)	0
Plan amendments	0	0
Foreign currency exchange rate changes	0	0
Ending balance	59	87	84
Change in Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	7	7
Benefit payments	(7)	(7)
Foreign currency exchange rate changes	0	0
Ending balance	0	0	0
Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	(59)	(87)
Unrecognized Net Actuarial (Gains) Losses	(32)	(10)
Unfunded Pension Plan
Change in Benefit Obligation
Beginning balance	249	256
Service cost	12	13
Interest cost	7	9
Actuarial (gains) loss	(29)	10
Benefit payments	(19)	(39)
Plan curtailments	(4)	0
Plan amendments	0	0
Foreign currency exchange rate changes	0	0
Ending balance	216	249	256
Change in Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	19	39
Benefit payments	(19)	(39)
Foreign currency exchange rate changes	0	0
Ending balance	0	0	$ 0
Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	(216)	(249)
Unrecognized Net Actuarial (Gains) Losses	$ 47	$ 84

Retirement Plans - Change in _2

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, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Lump-sum settlement payment included in Benefit payments	$ 32	$ 57
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	2,424	2,679
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Actuarial gains (loss) resulted from a change	29	(10)
Accumulated benefit obligation	171	190
Change in Discount Rate
Defined Benefit Plan Disclosure [Line Items]
Actuarial gains (loss) resulted from a change	$ 235	$ (170)

Retirement Plans - Amounts Reco

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	$ 76	$ 22
Current liabilities	0	0
Noncurrent liabilities	0	(55)
Pension assets / (accrued benefit liability)	76	(33)
Unrecognized Net Actuarial (Gains) Losses	778	789
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(9)	(11)
Noncurrent liabilities	(50)	(76)
Pension assets / (accrued benefit liability)	(59)	(87)
Unrecognized Net Actuarial (Gains) Losses	(32)	(10)
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(30)	(18)
Noncurrent liabilities	(186)	(231)
Pension assets / (accrued benefit liability)	(216)	(249)
Unrecognized Net Actuarial (Gains) Losses	$ 47	$ 84

Retirement Plans - Amounts Re_2

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Accumulated other comprehensive (gain) loss related to retirement plans, after-tax	$ 581	$ 548

Retirement Plans - Components o

Retirement Plans - Components of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 42	$ 49	$ 60
Interest cost	91	102	107
Expected return on plan assets	(194)	(168)	(166)
Amortization of unrecognized net actuarial losses (gains)	39	58	60
Settlement loss	4	19	0
Curtailment gain	0	0	0
Special termination benefit recognized	0	0	1
Net Periodic Benefit Cost	(18)	60	62
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	4	4
Interest cost	3	3	3
Expected return on plan assets	0	0	0
Amortization of unrecognized net actuarial losses (gains)	(2)	0	0
Settlement loss	0	0	0
Curtailment gain	(2)	0	0
Special termination benefit recognized	0	0	0
Net Periodic Benefit Cost	$ 1	$ 7	$ 7

Retirement Plans - Components_2

Retirement Plans - Components of Net Periodic Benefit Cost (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Compensation And Retirement Disclosure [Abstract]
Net non-service pension (income) costs included in Other, net	$ (61)	$ 14	$ 5

Retirement Plans - Actuarial As

Retirement Plans - Actuarial Assumptions Used for Pension Plans & Postretirement Medical Plan (Detail)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pension Plans
Benefit Obligations:
Discount rate	3.90%	3.30%	3.70%
Rate of compensation increase	3.80%	4.50%	4.60%
Net Periodic Benefit Cost:
Discount rate, Service cost	3.90%	3.70%	4.10%
Discount rate, Interest cost	3.30%	3.70%	4.10%
Expected return on plan assets	7.20%	7.30%	7.40%
Rate of compensation increase	4.50%	4.60%	4.50%
Postretirement Medical Plan
Benefit Obligations:
Discount rate	3.90%	3.20%	3.50%
Initial health care trend rate	6.90%	7.30%	7.70%
Ultimate trend rate	4.50%	4.50%	4.50%
Year in which ultimate trend rate is reached	2,038	2,038	2,038

Retirement Plans - Fair Value o

Retirement Plans - Fair Value of Financial Assets of Funded Pension Plans (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 2,568	$ 2,732
Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	50	101
U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	654	789
International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	409	434
Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	205	240
Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	240	271
Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	37	35
Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	186	166
Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	303	188
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	135	187
Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	170	140
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	160	157
Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	19	24
Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	800	990
Level 1 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	3	32
Level 1 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	654	789
Level 1 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	92	104
Level 1 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	2	2
Level 1 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 1 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	49	63
Level 1 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	1,006	991
Level 2 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	47	69
Level 2 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	29	34
Level 2 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	203	238
Level 2 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	240	271
Level 2 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	37	34
Level 2 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	159	139
Level 2 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	272	182
Level 2 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 2 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	19	24
Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	61	4	$ 10
Level 3 | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	1
Level 3 | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	1
Level 3 | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Level 3 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	61	2	$ 8
Level 3 | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	701	747
Net Asset Value | Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value | U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value | International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	288	296
Net Asset Value | Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value | Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value | Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
Net Asset Value | Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	27	26
Net Asset Value | Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	31	6
Net Asset Value | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	135	187
Net Asset Value | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	170	140
Net Asset Value | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	50	92
Net Asset Value | Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 0	$ 0

Retirement Plans - Changes in F

Retirement Plans - Changes in Financial Assets that are Measured at Fair Value Based on Level 3 Inputs that are held by Institutional Funds (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	$ 2,732
Ending balance	2,568	$ 2,732
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	157
Ending balance	160	157
Level 3
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	4	10
Actual return on plan assets	1	0
Purchases, sales or other settlements	56	(5)
Net transfers in (out) of Level 3	0	(1)
Ending balance	61	4
Level 3 | Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	2	2
Actual return on plan assets	0	0
Purchases, sales or other settlements	(2)	1
Net transfers in (out) of Level 3	0	(1)
Ending balance	0	2
Level 3 | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Beginning balance	2	8
Actual return on plan assets	1	0
Purchases, sales or other settlements	58	(6)
Net transfers in (out) of Level 3	0	0
Ending balance	$ 61	$ 2

Retirement Plans - Estimated Fu

Retirement Plans - Estimated Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan (Detail) $ in Millions	Dec. 31, 2018USD ($)
Compensation And Retirement Disclosure [Abstract]
2,019	$ 142
2,020	139
2,021	135
2,022	139
2,023	140
Years 2024 to 2028	$ 722

Share-based Compensation - Addi

Share-based Compensation - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of authorized common stock shares under LTIP, as amended	51,500,000
Number of shares under LTIP, as amended, available for issuance of restricted common shares, performance share units and stock options	19,000,000
Unearned compensation expense, before income taxes due 2019	$ 57
Unearned compensation expense, before income taxes due 2020	30
Unearned compensation expense, before income taxes due 2021	$ 6
Performance of predetermined peer companies	3 years
Outstanding stock options	5,200,000
Number of stock options, exercisable	3,900,000
Weighted average remaining contractual term - Outstanding	4 years 3 months 18 days
Weighted average remaining contractual life for options, exercisable	2 years 10 months 24 days
Aggregated intrinsic value	$ 0
Aggregated intrinsic value for exercisable options	$ 0
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period from date of grant, in years	3 years
Performance Share Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period from date of grant, in years	3 years
Minimum PSU awards payout	0.00%
Maximum PSU awards payout	200.00%
Stock Options
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period from date of grant, in years	3 years
Contractual term of stock options	10 years
Outstanding stock options	5,170,000	6,482,000
Weighted average remaining contractual term - Outstanding	4 years 3 months 18 days	3 years 7 months 6 days

Share-based Compensation - Shar

Share-based Compensation - Share-based Compensation Activity (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 72	$ 86	$ 73
Income tax benefit on share-based compensation expense		1	28
Restricted Stock
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	40	56	45
Stock Options
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	10	9	7
Performance Share Units
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 22	$ 21	$ 21

Share-based Compensation - Summ

Share-based Compensation - Summary of Restricted Stock Award Activity (Detail) - Restricted Stock shares in Thousands	12 Months Ended
	Dec. 31, 2018$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards - Outstanding at beginning of period | shares	3,202
Awards - Granted | shares	1,258
Awards - Vested | shares	(1,099)
Awards - Forfeited | shares	(480)
Awards - Outstanding at end of period | shares	2,881
Weighted average fair value on date of grant - Outstanding at beginning of period | $ / shares	$ 54.04
Weighted average fair value on date of grant - Granted | $ / shares	50.78
Weighted average fair value on date of grant - Vested | $ / shares	65.80
Weighted average fair value on date of grant - Forfeited | $ / shares	50.63
Weighted average fair value on date of grant - Outstanding at end of period | $ / shares	$ 48.70

Share-based Compensation - Su_2

Share-based Compensation - Summary of Restricted Stock Award Activity (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value of vested shares	$ 54	$ 37	$ 41

Share-based Compensation - Su_3

Share-based Compensation - Summary of PSU Activity (Detail) - Performance Share Units shares in Thousands	12 Months Ended
	Dec. 31, 2018$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards - Outstanding at beginning of period | shares	1,146
Awards - Granted | shares	278
Awards - Vested | shares	(313)
Awards - Forfeited | shares	(48)
Awards - Outstanding at end of period | shares	1,063
Weighted average fair value on date of grant - Outstanding at beginning of period | $ / shares	$ 58.78
Weighted average fair value on date of grant - Granted | $ / shares	59.65
Weighted average fair value on date of grant - Vested | $ / shares	76.64
Weighted average fair value on date of grant - Forfeited | $ / shares	53.62
Weighted average fair value on date of grant - Outstanding at end of period | $ / shares	$ 53.98

Share-based Compensation - Su_4

Share-based Compensation - Summary of PSU Activity (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Performance Share Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value of vested shares	$ 9	$ 10	$ 15

Share-based Compensation - Weig

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards (Detail) - Performance Share Units - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	2.39%	1.55%	0.96%
Stock price volatility	0.40%	0.387%	0.329%
Contractual term in years	3 years	3 years	3 years
Grant date price of Hess common stock	$ 48.48	$ 51.03	$ 44.31

Share-based Compensation - Su_5

Share-based Compensation - Summary of Stock Option Activity (Detail) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Exercised	(600)	(200)	(200)
Options - Outstanding at end of period	5,200
Weighted average remaining contractual term - Outstanding	4 years 3 months 18 days
Stock Options
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Outstanding at beginning of period	6,482
Options - Granted	683
Options - Exercised	(564)
Options - Forfeited	(1,431)
Options - Outstanding at end of period	5,170	6,482
Weighted average exercise price per share - Outstanding at beginning of period	$ 66.84
Weighted average exercise price per share - Granted	48.48
Weighted average exercise price per share - Exercised	55.84
Weighted average exercise price per share - Forfeited	80.23
Weighted average exercise price per share - Outstanding at end of period	$ 61.91	$ 66.84
Weighted average remaining contractual term - Outstanding	4 years 3 months 18 days	3 years 7 months 6 days

Share-based Compensation - We_2

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate the Fair Value of Stock Options (Detail) - Stock Options - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	2.74%	2.17%	1.47%
Stock price volatility	0.322%	0.333%	0.326%
Dividend yield	2.06%	1.96%	2.26%
Expected life in years	6 years	6 years	6 years
Weighted average fair value per option granted	$ 13.69	$ 14.51	$ 11.33

Exit and Disposal Costs - Addit

Exit and Disposal Costs - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restructuring And Related Activities [Abstract]
Severance expense	$ 38	$ 18	$ 55
Accrued severance costs paid	40	48	$ 52
Charges in connection with vacated office space	73	14
Accrued severance costs	4	6
Accrued liabilities for exit costs	$ 85	$ 28
Expected period for all payments for severance cost	Accrued severance costs are expected to be paid in 2019

Impairment - Additional Informa

Impairment - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Impairments [Line Items]
Impairment charge, pre-tax			$ 0	$ 4,203	$ 67
Fair value of estimated impairment charges determined using internal projected discounted cash flows	$ 1,100
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
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

Income Taxes - Components of In

Income Taxes - Components of Income Tax Provision (Benefit) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
United States - Federal, Current income tax expense (benefit)	$ 1	$ (23)	$ (27)
United States - Federal, Deferred income taxes and other accruals expense (benefit)	(74)	(6)	1,948
United States - State, Current & Deferred income taxes and other accruals expense (benefit)	(45)	0	23
United States, Current & Deferred income taxes and other accruals expense (benefit)	(118)	(29)	1,944
Current (b)	455	179	36
Foreign, Deferred income taxes and other accruals expense (benefit)	(2)	(1,987)	235
Foreign, Current & Deferred income taxes and other accruals expense (benefit)	453	(1,808)	271
Provision (benefit) for income taxes - before adjustments due to income tax law changes	335	(1,837)	2,215
Adjustment of deferred taxes for foreign income tax law changes	0	0	7
Total Provision (Benefit) For Income Taxes	$ 335	$ (1,837)	$ 2,222

Income Taxes - Components of _2

Income Taxes - Components of Income Tax Provision (Benefit) (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
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) Be

Income Taxes - Income (Loss) Before Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income (Loss) Before Income Taxes - United States	$ (219)	$ (2,784)	$ (2,431)
Income (Loss) Before Income Taxes - Foreign	439	(2,994)	(1,423)
Income (Loss) Before Income Taxes	$ 220	$ (5,778)	$ (3,854)

Income Taxes - Effective Income

Income Taxes - Effective Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
U.S. statutory rate	21.00%	35.00%	35.00%
Effect of foreign operations	141.20%	17.40%	4.60%
State income taxes, net of Federal income tax	(18.90%)	0.00%	1.90%
Change in enacted tax laws	0.00%	(23.60%)	(0.20%)
Valuation allowance adjustment with tax law change	0.00%	23.60%	0.00%
Rate differential on U.S. loss	0.00%	(4.10%)	0.00%
Gains on asset sales, net	0.00%	(2.20%)	0.00%
Impairment	0.00%	0.00%	(2.10%)
Valuation allowance on current year operations	55.20%	(14.90%)	0.00%
Valuation allowance against previously benefitted deferred tax assets	0.00%	0.10%	(97.30%)
Noncontrolling interest in partnership	(15.90%)	0.80%	0.50%
Intraperiod allocation	(37.30%)	(0.00%)	(0.00%)
Equity compensation shortfall	6.30%	(0.30%)	0.00%
Other	0.80%	0.00%	(0.10%)
Total	152.40%	31.80%	(57.70%)

Income Taxes - Effective Inco_2

Income Taxes - Effective Income Tax Rate Reconciliation (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Federal corporate tax rate	21.00%	35.00%	35.00%
Decrease in net deferred tax asset due to tax reform		$ 1,336

Income Taxes - Components of De

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Deferred Tax Liabilities
Property, plant and equipment and investments	$ (853)	$ (629)
Other	(77)	(24)
Total Deferred Tax Liabilities	(930)	(653)
Deferred Tax Assets
Net operating loss carryforwards	4,239	4,029
Tax credit carryforwards	134	138
Property, plant and equipment and investments	416	746
Accrued compensation, deferred credits and other liabilities	232	283
Asset retirement obligations	225	212
Other	161	36
Total Deferred Tax Assets	5,407	5,444
Valuation allowances	(4,877)	(5,199)
Total deferred tax assets, net of valuation allowances	530	245
Net Deferred Tax Assets (Liabilities)	$ (400)	$ (408)

Income Taxes - Components of _3

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ (322)	$ (251)	$ 3,872

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities, Net (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Deferred income taxes	$ 21	$ 21
Deferred income taxes (long-term liability)	(421)	(429)
Net Deferred Tax Assets (Liabilities)	$ (400)	$ (408)

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Income Tax Examination [Line Items]
Gross deferred tax asset related to net operating loss carryforwards	$ 4,239,000,000	$ 4,029,000,000
Gross deferred tax asset related to foreign net operating loss carryforwards	1,382,000,000
Gross deferred tax asset related to net U.S. federal operating loss carryforwards	2,386,000,000
Gross deferred tax asset related to net operating loss carryforwards for various U.S. states	471,000,000
Deferred tax asset related to foreign net operating loss carryforwards, net of valuation allowance	12,000,000
Alternative minimum tax credit carryforwards	49,000,000
Other business credit carryforwards	15,000,000
Deferred tax asset related to business credit carryforwards, net of valuation allowance	1,000,000
Foreign tax credit carryforwards - Before valuation allowance	$ 70,000,000
Year in which foreign tax credit carryforwards begin to expire	2,019
Valuation allowance against net deferred tax assets	$ 4,877,000,000	5,199,000,000
Period of cumulative loss incurred	3 years
Unrecognized tax benefits that would impact effective income tax rate	$ 7,000,000
Accrued interest and penalties	3,000,000	$ 23,000,000
Minimum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible	2,000,000
Maximum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible	$ 8,000,000
Foreign
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 1, 2025
U.S. Federal
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 1, 2035
U.S. State
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 1, 2019

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Balance at January 1	$ 205	$ 424	$ 604
Additions based on tax positions taken in the current year	19	14	19
Additions based on tax positions of prior years	36	4	113
Reductions based on tax positions of prior years	(78)	(147)	(274)
Reductions due to settlements with taxing authorities	(10)	(85)	(27)
Reductions due to lapses in statutes of limitation	(4)	(5)	(11)
Balance at December 31	$ 168	$ 205	$ 424

Basic and Diluted Earnings Pe_3

Basic and Diluted Earnings Per Common Share - Net Income (Loss) and Weighted Average Number of Common Shares Used in Computation of Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Net Income (Loss)	$ (115)	$ (3,941)	$ (6,076)
Less: Net income (loss) attributable to noncontrolling interests	167	133	56
Less: Preferred stock dividends	46	46	41
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (328)	$ (4,120)	$ (6,173)
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Basic	298.2	314.1	309.9
Diluted	298.2	314.1	309.9
Basic	$ (1.10)	$ (13.12)	$ (19.92)
Diluted	$ (1.10)	$ (13.12)	$ (19.92)
Restricted Common Stock
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	2.9	3.3	3.3
Stock Options
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	5.5	6.4	6.9
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	1.1	0.6	0.9
Common Shares From Conversion Of Preferred Stocks
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	12.7	12.8	11.2
Restricted Common Stock
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0	0	0
Stock Options
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0	0	0
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0	0	0
Mandatory Convertible Preferred Stock
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0	0	0

Common and Preferred Stock - Ch

Common and Preferred Stock - Changes in Outstanding Common Shares (Detail) - shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Stockholders Equity Note [Abstract]
Balance at January 1	315,100,000	316,500,000	286,000,000
Shares issued	0	0	28,800,000
Activity related to restricted stock awards, net	800,000	800,000	1,100,000
Stock options exercised	600,000	200,000	200,000
PSU vested	100,000	200,000	400,000
Shares repurchased	(25,200,000)	(2,600,000)	0
Balance at December 31	291,400,000	315,100,000	316,500,000

Common and Preferred Stock - Ad

Common and Preferred Stock - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended												12 Months Ended
	Feb. 29, 2016	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	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, 2018	Dec. 31, 2017	Dec. 31, 2016
Class Of Stock [Line Items]
Shares of stock issued														0	0	28,800,000
Cumulative mandatory convertible series														8.00%	8.00%
Preferred stock, par value		$ 1				$ 1								$ 1	$ 1
Preferred stock, liquidation preference per share		$ 1,000				1,000								$ 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															$ 1,600
Common stock repurchased, share repurchase program														$ 1,380	$ 120
Common stock repurchased, share repurchase program, share														25,200,000	2,600,000	0
Additional amount of common stock that may be repurchased		$ 650												$ 650
Average cost per share														$ 54.85	$ 45.67
Cash dividends on common stock		$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 0.25	$ 1	$ 1	$ 1
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, Exceeds $45.83
Class Of Stock [Line Items]
Shares covered by cap call	12,550,000
Series A Mandatory Convertible Preferred Stock | Final Average Price between $45.83 and $53.625
Class Of Stock [Line Items]
Shares covered by cap call	12,550,000
Series A Mandatory Convertible Preferred Stock | Final Average Price, $45.83
Class Of Stock [Line Items]
Shares covered by cap call	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
Common stock repurchased, share repurchase program														$ 25	$ 3
Capital in Excess of Par
Class Of Stock [Line Items]
Common stock repurchased, share repurchase program														$ 541	$ 43
Capital in Excess of Par | Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Premium paid for capped call transaction	$ 37															$ 37

Supplementary Cash Flow Infor_3

Supplementary Cash Flow Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities
Interest paid	$ (394)	$ (314)	$ (338)
Net income taxes (paid) refunded	(463)	(210)	132
Cash Flows from Investing Activities
Additions to property, plant and equipment - E&P	(1,854)	(1,788)	(1,974)
Exploration and Production
Cash Flows from Investing Activities
Capital expenditures incurred	(1,909)	(1,852)	(1,638)
Increase (decrease) in related liabilities	55	64	(336)
Additions to property, plant and equipment - E&P	(1,854)	(1,788)	(1,974)
Midstream
Cash Flows from Investing Activities
Capital expenditures incurred	(271)	(121)	(283)
Increase (decrease) in related liabilities	28	(28)	6
Additions to property, plant and equipment - Midstream	$ (243)	$ (149)	$ (277)

Leased Assets - Future Minimum

Leased Assets - Future Minimum Rental Payments (Detail) $ in Millions	Dec. 31, 2018USD ($)
Leases [Abstract]
2,019	$ 355
2,020	156
2,021	65
2,022	64
2,023	64
Remaining years	198
Total Minimum Lease Payments	902
Less: Income from subleases	114
Net Minimum Lease Payments	$ 788

Leased Assets - Rental Expense

Leased Assets - Rental Expense (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Leases [Abstract]
Total rental expense	$ 154	$ 123	$ 106
Less: Income from subleases	8	10	5
Net Rental Expense	$ 146	$ 113	$ 101

Guarantees, Contingencies and_3

Guarantees, Contingencies and Commitments - Additional Information (Detail) $ in Millions	Mar. 04, 2016USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2018USD ($)Case
MTBE Cases
Loss Contingencies [Line Items]
Total number of remaining active cases filed | Case			3
Lower Passaic River
Loss Contingencies [Line Items]
Estimated remediation cost	$ 1,380
Gowanus Canal Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost		$ 506
Ector Drum, Inc. Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost			$ 3.5

Guarantees, Contingencies and_4

Guarantees, Contingencies and Commitments - Schedule of Unconditional Purchase Obligations and Commitments (Detail) $ in Millions	Dec. 31, 2018USD ($)
Capital Expenditures
Loss Contingencies [Line Items]
Total	$ 1,069
2,019	443
2020 and 2021	551
2022 and 2023	75
Thereafter	0
Operating Expenses
Loss Contingencies [Line Items]
Total	433
2,019	219
2020 and 2021	99
2022 and 2023	61
Thereafter	54
Transportation and Related Contracts
Loss Contingencies [Line Items]
Total	1,050
2,019	212
2020 and 2021	401
2022 and 2023	336
Thereafter	$ 101

Segment Information - Additiona

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2018Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	2

Segment Information - Financial

Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	$ 6,323	$ 5,466	$ 4,762
Intersegment revenues	0	0	0
Total sales and other operating revenues	6,323	5,466	4,762
Net Income (Loss) Attributable to Hess Corporation	(282)	(4,074)	(6,132)
Interest Expense	399	325	338
Depreciation, Depletion and Amortization	1,883	2,883	3,244
Impairment	0	4,203	67
Provision (Benefit) for Income Taxes	335	(1,837)	2,222
Investment in Affiliates	193	134
Identifiable Assets	21,433	23,112
Capital Expenditures	2,180	1,973	1,921
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0
Intersegment revenues	(713)	(611)	(562)
Total sales and other operating revenues	(713)	(611)	(562)
Net Income (Loss) Attributable to Hess Corporation	0	0	0
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	0	0	0
Impairment		0	0
Provision (Benefit) for Income Taxes	0	0	0
Investment in Affiliates	0	0
Identifiable Assets	0	0
Capital Expenditures	0	0	0
Exploration and Production | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	6,323	5,460	4,755
Intersegment revenues	0	0	0
Total sales and other operating revenues	6,323	5,460	4,755
Net Income (Loss) Attributable to Hess Corporation	51	(3,653)	(4,964)
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	1,748	2,736	3,113
Impairment		4,203	0
Provision (Benefit) for Income Taxes	391	(1,842)	1,587
Investment in Affiliates	126	134
Identifiable Assets	16,109	15,613
Capital Expenditures	1,909	1,852	1,638
Midstream
Segment Reporting Information [Line Items]
Impairment			67
Midstream | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	6	7
Intersegment revenues	713	611	562
Total sales and other operating revenues	713	617	569
Net Income (Loss) Attributable to Hess Corporation	120	42	42
Interest Expense	60	26	19
Depreciation, Depletion and Amortization	127	123	121
Impairment		0	67
Provision (Benefit) for Income Taxes	38	31	26
Investment in Affiliates	67	0
Identifiable Assets	3,285	3,329
Capital Expenditures	271	121	283
Corporate, Interest and Other | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0
Intersegment revenues	0	0	0
Total sales and other operating revenues	0	0	0
Net Income (Loss) Attributable to Hess Corporation	(453)	(463)	(1,210)
Interest Expense	339	299	319
Depreciation, Depletion and Amortization	8	24	10
Impairment		0	0
Provision (Benefit) for Income Taxes	(94)	(26)	609
Investment in Affiliates	0	0
Identifiable Assets	2,039	4,170
Capital Expenditures	$ 0	$ 0	$ 0

Segment Information - Financi_2

Segment Information - Financial Information by Major Geographic Area (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 6,323	$ 5,466	$ 4,762
Net Income (Loss) Attributable to Hess Corporation	(282)	(4,074)	(6,132)
Depreciation, Depletion and Amortization	1,883	2,883	3,244
Impairment	0	4,203	67
Provision (benefit) for income taxes	335	(1,837)	2,222
Identifiable Assets	21,433	23,112
Property, Plant and Equipment (Net)	16,083	16,192
Capital Expenditures	2,180	1,973	1,921
Operating Segments | Corporate, Interest and Other
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0	0
Net Income (Loss) Attributable to Hess Corporation	(453)	(463)	(1,210)
Depreciation, Depletion and Amortization	8	24	10
Impairment		0	0
Provision (benefit) for income taxes	(94)	(26)	609
Identifiable Assets	2,039	4,170
Property, Plant and Equipment (Net)	15	23
Capital Expenditures	0	0	0
United States
Segment Reporting Information [Line Items]
Sales and other operating revenues	4,842	3,692	3,085
Net Income (Loss) Attributable to Hess Corporation	131	(2,433)	(2,353)
Depreciation, Depletion and Amortization	1,424	1,942	2,133
Impairment		1,700	67
Provision (benefit) for income taxes	(25)	0	411
Identifiable Assets	13,250	13,640
Property, Plant and Equipment (Net)	11,653	11,894
Capital Expenditures	1,543	1,387	1,400
Europe | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	164	629	610
Net Income (Loss) Attributable to Hess Corporation	42	(1,383)	(439)
Depreciation, Depletion and Amortization	37	381	502
Impairment		2,503	0
Provision (benefit) for income taxes	15	(1,999)	243
Identifiable Assets	1,033	1,024
Property, Plant and Equipment (Net)	906	946
Capital Expenditures	8	141	59
Africa | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	548	675	601
Net Income (Loss) Attributable to Hess Corporation	36	259	(355)
Depreciation, Depletion and Amortization	19	263	375
Impairment		0	0
Provision (benefit) for income taxes	430	197	244
Identifiable Assets	395	428
Property, Plant and Equipment (Net)	355	365
Capital Expenditures	9	30	10
Asia and Other Countries | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	769	470	466
Net Income (Loss) Attributable to Hess Corporation	(38)	(54)	(1,775)
Depreciation, Depletion and Amortization	395	273	224
Impairment		0	0
Provision (benefit) for income taxes	9	(9)	715
Identifiable Assets	4,716	3,850
Property, Plant and Equipment (Net)	3,154	2,964
Capital Expenditures	$ 620	$ 415	$ 452

Financial Risk Management Act_3

Financial Risk Management Activities - Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts (Detail) - WTI	12 Months Ended
	Dec. 31, 2018MMBbls$ / bbl	Dec. 31, 2017MMBbls$ / bbl
2,019
Derivative [Line Items]
Calendar year program	2,019
Instrument type	Puts
Crude oil volumes (millions of barrels) | MMBbls	34.7
Ceiling price	0
Floor price	60
2,018
Derivative [Line Items]
Calendar year program		2,018
Instrument type	Collars
Crude oil volumes (millions of barrels) | MMBbls		42
Ceiling price		65
Floor price		50

Financial Risk Management Act_4

Financial Risk Management Activities - Additional Information (Detail) - West Texas Intermediate Crude Oil Price Hedging Contracts	12 Months Ended
	Dec. 31, 2018bbl / d$ / bbl	Dec. 31, 2017bbl / d$ / bbl
2,018
Derivative Instruments Gain Loss [Line Items]
Monthly floor price		50
Monthly ceiling price		65
Notional amount of outstanding average barrels of oil per day | bbl / d		115,000
2018 | Designated as Cash Flow Hedges
Derivative Instruments Gain Loss [Line Items]
Monthly floor price		50
Monthly ceiling price		65
2,019
Derivative Instruments Gain Loss [Line Items]
Monthly floor price	60
Monthly ceiling price	0
2019 | Designated as Cash Flow Hedges
Derivative Instruments Gain Loss [Line Items]
Monthly floor price	60
Notional amount of outstanding average barrels of oil per day | bbl / d	95,000

Financial Risk Management Act_5

Financial Risk Management Activities - Gross Notional Amounts of Derivative Contracts Outstanding Excluding Commodity Contracts (Detail) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Foreign Exchange
Derivative [Line Items]
Outstanding gross notional amount	$ 16,000,000	$ 52,000,000
Interest Rate Swaps | Designated as Fair Value Hedges
Derivative [Line Items]
Outstanding gross notional amount	$ 100,000,000	$ 450,000,000

Financial Risk Management Act_6

Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 484	$ 1
Assets – Master netting arrangements	0	0
Assets - Net Fair Value of Derivative Contracts	484	1
Liabilities - Gross fair value of derivative contracts	(2)	(13)
Liabilities - Master netting arrangements	0	0
Liabilities - Net Fair Value of Derivative Contracts	(2)	(13)
Derivative Contracts Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	484	0
Liabilities - Gross fair value of derivative contracts	(2)	(11)
Derivative Contracts Designated as Hedging Instruments | Commodity | Other Current Assets
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	484
Liabilities - Gross fair value of derivative contracts	0
Derivative Contracts Designated as Hedging Instruments | Commodity | Accounts Payable
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		0
Liabilities - Gross fair value of derivative contracts		(7)
Derivative Contracts Designated as Hedging Instruments | Interest Rate | Other assets (noncurrent) and Accounts Payable
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		0
Liabilities - Gross fair value of derivative contracts		(4)
Derivative Contracts Designated as Hedging Instruments | Interest Rate | Other Liabilities and Deferred Credits
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	0
Liabilities - Gross fair value of derivative contracts	$ (2)
Derivative Contracts Not Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		1
Liabilities - Gross fair value of derivative contracts		(2)
Derivative Contracts Not Designated as Hedging Instruments | Commodity | Accounts Payable
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		0
Liabilities - Gross fair value of derivative contracts		(2)
Derivative Contracts Not Designated as Hedging Instruments | Foreign Exchange | Accounts Receivable | Joint Venture and Other
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		1
Liabilities - Gross fair value of derivative contracts		$ 0

Financial Risk Management Act_7

Financial Risk Management Activities - Corporate Financial Risk Management Activities - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments Gain Loss [Line Items]
Amount of terminated interest rate swaps	$ 350,000,000
Cumulative currency translation gain (losses) recognized in earnings	0	$ (900,000,000)	$ 0
Interest Rate Swaps | Designated as Fair Value Hedges
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	100,000,000	450,000,000
Amount of cash proceeds received from settled interest rate swaps		0	5,000,000
Unrealized change in fair value of interest rate swaps - increase in derivative liability/(increase in asset)	(1,000,000)	(4,000,000)	6,000,000
Payment to terminate interest rate swaps	3,000,000
Interest Rate Swaps | Designated as Cash Flow Hedges
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount		553,000,000
Payment to settle interest rate swaps		3,000,000
Foreign Exchange
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	16,000,000	52,000,000
Total foreign exchange gains and (losses) reported in Other, net in Revenues and Non-Operating Income in the Statement of Consolidated Income	(5,000,000)	15,000,000	26,000,000
Gain (Loss) on foreign exchange contracts not designated as hedging instruments	(2,000,000)	3,000,000	62,000,000
After tax foreign currency translation adjustments included in Accumulated other comprehensive income (loss)		144,000,000	56,000,000
Derivative Contracts Designated as Hedging Instruments | Crude Oil
Derivative Instruments Gain Loss [Line Items]
Crude oil price hedging contracts increased (decreased) sales and other operating revenues by this amount, pre-tax	161,000,000	34,000,000	$ 0
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings during the next 12 months	365,000,000
Derivative Contracts Not Designated as Hedging Instruments | Crude Oil
Derivative Instruments Gain Loss [Line Items]
Crude oil price hedging contracts increased (decreased) sales and other operating revenues by this amount, pre-tax	$ (22,000,000)	$ (25,000,000)

Financial Risk Management Act_8

Financial Risk Management Activities - Credit Risk - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Letters of credit – Issued	$ 284	$ 246
Financial Institutions
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	34.00%
Integrated Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	24.00%
Independent E&P Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	22.00%
National Oil Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	7.00%
Storage and Transportation Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	3.00%
Refining and Marketing Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	5.00%
Others
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	5.00%

Financial Risk Management Act_9

Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Dec. 31, 2018USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt excluding capital lease, carrying value	$ 6,672
Carrying value
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt excluding capital lease, carrying value	6,403
Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt excluding capital lease, fair value	$ 6,225

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail) - shares	Jan. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsequent Event [Line Items]
Series A, cumulative mandatory convertible preferred stock - dividend rate		8.00%	8.00%
Series A Mandatory Convertible Preferred Stock | Subsequent Event
Subsequent Event [Line Items]
Common stock issuance following preferred stock conversion	12,500,000
Series A, cumulative mandatory convertible preferred stock - dividend rate	8.00%
Number of common shares received from capped call upon conversion of preferred stocks	0.9
Net number of common shares issued upon conversion of preferred stocks	11,600,000
Convertible preferred stock conversion in to common stock converted shares	21.822