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Debt (Tables)

12 Months Ended

Dec. 31, 2019

Total debt at December 31 consisted of the following:

	2019		2018
	(In millions)
Debt - Hess Corporation:
Fixed-rate public notes:
3.5% due 2024	$	298	$	298
4.3% due 2027		992		992
7.9% due 2029		463		463
7.3% due 2031		628		627
7.1% due 2033		537		537
6.0% due 2040		741		740
5.6% due 2041		1,235		1,234
5.8% due 2047		494		493
Total fixed-rate public notes		5,388		5,384
Capital lease obligations (a)		—		269
Financing obligations associated with floating production system (a)		—		40
Fair value adjustments - interest rate hedging		1		(2	)
Total Debt - Hess Corporation	$	5,389	$	5,691

Debt - Midstream:
Fixed-rate notes: 5.6% due 2026 - Hess Midstream Operations LP	$	787	$	—
Fixed-rate notes: 5.1% due 2028 - Hess Midstream Operations LP		540		—
Fixed-rate notes: 5.6% due 2026 - HIP		—		787
Term loan A facility - Hess Midstream Operations LP		394		—
Term loan A facility - HIP		—		194
Revolving credit facility - Hess Midstream Operations LP		32		—
Total Debt - Midstream	$	1,753	$	981

Total Debt:
Current maturities of long-term debt	$	—	$	67
Long-term debt		7,142		6,605
Total Debt	$	7,142	$	6,672

(a)	Upon adoption of ASC 842, Leases on January 1, 2019, capital lease and financing obligations previously included in Debt were reclassified to Finance leases.

Maturity Profile of Total Debt

At December 31, 2019, the maturity profile of total debt was as follows:

	Total			Hess Corporation			Midstream
	(In millions)
2020	$	—		$	—		$	—
2021		10			—			10
2022		20			—			20
2023		30			—			30
2024		672			300			372
Thereafter		6,488			5,138			1,350
Total Borrowings		7,220			5,438			1,782
Less: Deferred issuance costs		(78	)		(49	)		(29	)
Total Debt (excluding interest)	$	7,142		$	5,389		$	1,753

Other Outstanding Letters of Credit

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

	2019		2018
	(In millions)
Committed lines (a)	$	54	$	29
Uncommitted lines (a)		218		255
Total	$	272	$	284

(a)	At December 31, 2019, committed and uncommitted lines have expiration dates throughout 2020.

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 1,545	$ 2,694
Accounts receivable:
From contracts with customers	940	771
Joint venture and other	230	230
Inventories	261	245
Other current assets	180	519
Total current assets	3,156	4,459
Property, plant and equipment:
Total — at cost	35,820	33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment	19,006	17,139
Property, plant and equipment — net	16,814	16,083
Operating lease right-of-use assets — net	447	0
Finance lease right-of-use assets — net	299	0
Goodwill	360	360
Deferred income taxes	80	21
Other assets	626	510
Total Assets	21,782	21,433
Current Liabilities:
Accounts payable	411	495
Accrued liabilities	1,803	1,560
Taxes payable	97	81
Current maturities of long-term debt	0	67
Current portion of operating and finance lease obligations	199	0
Total current liabilities	2,510	2,203
Long-term debt	7,142	6,605
Long-term operating lease obligations	353	0
Long-term finance lease obligations	238	0
Deferred income taxes	415	421
Asset retirement obligations	897	741
Other liabilities and deferred credits	521	575
Total Liabilities	12,076	10,545
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 zero shares (2018: 574,997)	0	1
Common stock, par value $1.00; Authorized 600,000,000 shares Issued 304,955,472 shares (2018: 291,434,534)	305	291
Capital in excess of par value	5,591	5,386
Retained earnings	3,535	4,257
Accumulated other comprehensive income (loss)	(699)	(306)
Total Hess Corporation stockholders’ equity	8,732	9,629
Noncontrolling interests	974	1,259
Total equity	9,706	10,888
Total Liabilities and Equity	$ 21,782	$ 21,433

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ (240)	$ (115)	$ (3,941)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	(1)	173	18
Income taxes on effect of hedge (gains) losses reclassified to income	0	0	0
Net effect of hedge (gains) losses reclassified to income	(1)	173	18
Change in fair value of cash flow hedges	(462)	330	(156)
Income taxes on change in fair value of cash flow hedges	86	(86)	0
Net change in fair value of cash flow hedges	(376)	244	(156)
Change in derivatives designated as cash flow hedges, after taxes	(377)	417	(138)
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	(160)	29	35
Income taxes on actuarial changes in plan liabilities	0	(6)	0
(Increase) reduction in unrecognized actuarial losses, net	(160)	23	35
Amortization of net actuarial losses	144	41	77
Income taxes on amortization of net actuarial losses	0	0	0
Net effect of amortization of net actuarial losses	144	41	77
Change in pension and other postretirement plans, after taxes	(16)	64	112
Foreign currency translation adjustment
Foreign currency translation adjustment	0	0	144
Asset disposition	0	0	900
Change in foreign currency translation adjustment	0	0	1,044
Other Comprehensive Income (Loss)	(393)	481	1,018
Comprehensive Income (Loss)	(633)	366	(2,923)
Less: Comprehensive income (loss) attributable to noncontrolling interests	168	167	133
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (801)	$ 199	$ (3,056)

Inventories - Inventories (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 92	$ 74
Materials and supplies	169	171
Total Inventories	$ 261	$ 245

Asset Retirement Obligations - Changes to Asset Retirement Obligations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 857	$ 801
Liabilities incurred	72	68
Liabilities settled or disposed of	(75)	(46)
Accretion expense	40	37
Revisions of estimated liabilities	129	1
Foreign currency remeasurement	1	(4)
Asset retirement obligations at end of period	1,024	857
Current portion of asset retirement obligations	127	116
Long-term asset retirement obligations	$ 897	$ 741

Nature of Operations, Basis of Presentation and Summary of Accounting Policies

12 Months Ended

Dec. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Nature of Operations, Basis of Presentation and Summary of Accounting Policies

1. Nature of Operations, Basis of Presentation and Summary of Accounting Policies

Unless the context indicates otherwise, references to “Hess”, “the Corporation”, “Registrant”, “we”, “us” and “our” refer to the consolidated business operations of Hess Corporation and its affiliates.

Nature of Business: Hess Corporation, incorporated in the State of Delaware in 1920, is a global Exploration and Production (E&P) company engaged in exploration, development, production, transportation, purchase and sale of crude oil, NGL, and natural gas with production operations and development activities located primarily in the United States (U.S.), Guyana, the Malaysia/Thailand Joint Development Area (JDA), Malaysia and Denmark. We conduct exploration activities primarily offshore Guyana, the U.S. Gulf of Mexico, and offshore Suriname and Canada.

Our Midstream operating segment, which is comprised of Hess Corporation’s 47% consolidated ownership interest in Hess Midstream LP at December 31, 2019 (see Note 6, Hess Midstream) provides fee-based services, including gathering, compressing and processing natural gas and fractionating NGL; gathering, terminaling, loading and transporting crude oil and NGL; storing and terminaling propane, and water handling services primarily in the Bakken shale play 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. Commencing December 16, 2019, we consolidate Hess Midstream LP, a variable interest entity that acquired Hess Infrastructure Partners LP (HIP), based on our conclusion that we have the power through Hess Corporation’s 47% consolidated ownership interest in Hess Midstream LP to direct those activities that most significantly impact the economic performance of Hess Midstream LP, and are obligated to absorb losses or have the right to receive benefits that could potentially be significant to Hess Midstream LP. Prior to December 16, 2019, we consolidated HIP, also a variable interest entity based on the conclusion we had the power to direct the activities that most significantly impact the economic performance of 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.

On January 1, 2019, we adopted Accounting Standards Codification (ASC) Topic 842, Leases. ASC 842 supersedes ASC 840 and requires the recognition of right-of-use (ROU) assets and lease obligations for all leases with lease terms greater than one year, including leases previously treated as operating leases under ASC 840. We adopted ASC 842 using the modified retrospective method which allows the standard to be applied prospectively. No cumulative effect adjustment was recorded to Retained Earnings at January 1, 2019, and comparative financial statements for periods prior to adoption of ASC 842 were not affected. We elected to apply a number of practical expedients permitted by the standard, 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 also elected to not recognize a lease liability or ROU asset for short-term leases as defined in ASC 842. This standard does not apply to leases acquired for oil and gas producing activities that are accounted for under ASC 932, Extractive Activities – Oil and Gas.

The adoption of ASC 842 did not have an impact on our Statement of Consolidated Income or Statement of Consolidated Cash Flows. The impact of adoption on our Consolidated Balance Sheet on January 1, 2019, was as follows:

	December 31, 2018		Adjustment for Finance Leases			Adjustment for Operating Leases			January 1, 2019
	(In millions)
Assets
Property, plant and equipment — net	$	16,083	$	(346	)	$	—		$	15,737
Operating lease right-of-use assets — net		—		—			804			804
Finance lease right-of-use assets — net		—		346			—			346
Liabilities
Accrued liabilities		1,560		—			(2	)		1,558
Current maturities of long-term debt		67		(55	)		—			12
Current portion of operating and finance lease obligations		—		55			382			437
Long-term debt		6,605		(254	)		—			6,351
Long-term operating lease obligations		—		—			516			516
Long-term finance lease obligations		—		254			—			254
Other liabilities and deferred credits		575		—			(92	)		483

In 2019, we adopted Accounting Standards Update (ASU) 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. This ASU makes certain targeted improvements to the accounting for income taxes by removing certain exceptions to the general principles in Topic 740, including removal of the exception to the incremental approach for intraperiod

tax allocation when there is a loss from continuing operations and income or gain from other items, such as other comprehensive income. The amendments also improve consistent application of and simplify U.S. generally accepted accounting principles (GAAP) for other areas of Topic 740 by clarifying and amending existing guidance. This ASU is effective for us beginning in the first quarter of 2021, with early adoption permitted. We elected to adopt this ASU effective October 1, 2019, and the adoption had no impact on our Consolidated Financial Statements.

Estimates and Assumptions: In preparing financial statements in conformity with 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:

Exploration and Production

The E&P segment recognizes revenue from the sale of crude oil, NGL, 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, NGL, 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 within Sales and other operating revenues and Marketing, including purchased oil and gas, respectively. Where control of crude oil, NGL, or natural gas is not transferred to Hess, revenue is presented net of the associated cost of purchased volumes within Sales and other operating revenues in the Statement of Consolidated Income.

Contract types:

The following is a summary of contract types for our E&P segment:

Crude oil, NGL, and natural gas – United States (U.S.): Contracts with customers for the sale of U.S. crude oil, NGL, 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 NGL that have remaining durations ranging from one to twelve 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, NGL, 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. At December 31, 2019 and 2018, there were no contract assets or contract liabilities.

Generally, we receive payments from customers on a monthly basis, shortly after the physical delivery of the crude oil, NGL, or natural gas. We did not recognize any credit losses on receivables with customers during 2019 nor 2018.

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 the exemption from disclosure of revenue recognizable in future periods as these performance obligations are satisfied.

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 price 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, Revenue from Contracts with Customers to recognize revenue in the amount it is entitled to invoice. If the commercial agreements have ship-or-pay provisions, the Midstream segment’s responsibility to stand-ready to service a minimum volume over each quarterly commitment period represent separate, distinct performance obligations. Shortfall payments received under ship-or-pay provisions are recognized as revenue in the calendar quarter the shortfall occurs as the customer does not have make-up rights beyond the calendar quarter end of the quarterly commitment period. All revenues, receivables, and contract balances arising from the commercial agreements between the Midstream segment and the Hess marketing subsidiary that is the counterparty to the commercial agreements are eliminated upon consolidation.

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 or when events or circumstances indicate that the carrying amount of the goodwill may not be recoverable. To determine whether an indicator of impairment exists, the fair value of a reporting unit is compared with its carrying amount, including goodwill. If the fair value of the reporting unit exceeds its carrying value, goodwill is not impaired. If the carrying value of the reporting unit exceeds its fair value, an impairment charge would be recorded for the excess of the carrying value over fair value, limited by the amount of goodwill allocated to the reporting unit. At December 31, 2019, goodwill of $360 million relates to the Midstream operating segment.

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 NGL 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 any carryback or carryforward period so brief that a significant deductible temporary difference expected to reverse in a single year would limit realization of tax benefits. 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. 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. Our policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized currently in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges), or hedges of changes in fair value of recognized assets and liabilities or of unrecognized firm commitments (fair value hedges). Changes in fair value of derivatives that are designated as cash flow hedges are recorded as a component of other comprehensive income (loss). Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings. Changes in fair value of derivatives designated as fair value hedges are recognized currently in earnings. The change in fair value of the related hedged commitment is recorded as an adjustment to its carrying amount and recognized currently in earnings.

Fair Value Measurements: We use various valuation approaches in determining fair value for financial instruments, including the market and income approaches. Our fair value measurements also include non-performance risk and time value of money considerations. Counterparty credit is considered for receivable balances, and our credit is considered for accrued liabilities. We also record certain nonfinancial assets and liabilities at fair value when required by GAAP. These fair value measurements are recorded in connection with business combinations, qualifying nonmonetary exchanges, the initial recognition of asset retirement obligations and any impairment of long‑lived assets, equity method investments or goodwill. We determine fair value in accordance with the fair value measurements accounting standard which established a hierarchy for the inputs used to measure fair value based on the source of the inputs, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using related market data (Level 3), including discounted cash flows and other unobservable data. Measurements derived indirectly from observable inputs or from quoted prices from markets that are less liquid are considered Level 2. When Level 1 inputs are available within a particular market, those inputs are selected for determination of fair value over Level 2 or 3 inputs in the same market. Multiple inputs may be used to measure fair value; however, the level of fair value 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 (PSUs). 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 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 2019, our reserve for estimated remediation liabilities was approximately $70 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 June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared with the current "incurred loss" model. We will adopt this ASU in the first quarter of 2020 when the standard becomes effective and it is not expected to have a material impact on our consolidated financial statements.

Debt - Components of Debt (Parenthetical) (Detail)	12 Months Ended
Debt - Components of Debt (Parenthetical) (Detail)	Dec. 31, 2019
3.5% Due 2024
Debt Instrument [Line Items]
Coupon rate	3.50%
Maturity year	2024
4.3% due 2027
Debt Instrument [Line Items]
Coupon rate	4.30%
Maturity year	2027
7.9% Due 2029
Debt Instrument [Line Items]
Coupon rate	7.90%
Maturity year	2029
7.3% Due 2031
Debt Instrument [Line Items]
Coupon rate	7.30%
Maturity year	2031
7.1% Due 2033
Debt Instrument [Line Items]
Coupon rate	7.10%
Maturity year	2033
6.0% Due 2040
Debt Instrument [Line Items]
Coupon rate	6.00%
Maturity year	2040
5.6% Due 2041
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2041
5.8% Due 2047
Debt Instrument [Line Items]
Coupon rate	5.80%
Maturity year	2047
5.6% Due 2026
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2026
5.1% Due 2028
Debt Instrument [Line Items]
Coupon rate	5.10%
Maturity year	2028
5.6% Due 2026 HIP
Debt Instrument [Line Items]
Coupon rate	5.60%
Maturity year	2026

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	$ 71	$ 76
Current liabilities	0	0
Noncurrent liabilities	(6)	0
Pension assets / (accrued benefit liability)	65	76
Unrecognized Net Actuarial (Gains) Losses	756	778
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(8)	(9)
Noncurrent liabilities	(67)	(50)
Pension assets / (accrued benefit liability)	(75)	(59)
Unrecognized Net Actuarial (Gains) Losses	(12)	(32)
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(32)	(30)
Noncurrent liabilities	(210)	(186)
Pension assets / (accrued benefit liability)	(242)	(216)
Unrecognized Net Actuarial (Gains) Losses	$ 65	$ 47

Dispositions - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales	$ 22	$ 607	$ 3,296
Gain (loss) on asset sales, pre-tax	22	32	(86)
Loss included recognition earnings for cumulative translation adjustments	0	0	900
Miscellaneous Non-core Assets
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset sales			194
Gain (loss) on asset sales, pre-tax			12
Gain (loss) on asset sale, after income taxes			12
Ghana
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Agreement entered to sell interest, total consideration		100
Proceeds from asset sales		25
Gain (loss) on asset sales, pre-tax		10
Gain (loss) on asset sale, after income taxes		10
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 income taxes			486
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	22	396
Gain (loss) on asset sales, pre-tax	22	14
Gain (loss) on asset sale, after income taxes	$ 22	$ 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 and non-controlling interests			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 and non-controlling interests			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 and non-controlling interests			(34)
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 income taxes			(857)
Loss included recognition earnings for cumulative translation adjustments			$ 900

Debt

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

Debt

8. Debt

Total debt at December 31 consisted of the following:

	2019		2018
	(In millions)
Debt - Hess Corporation:
Fixed-rate public notes:
3.5% due 2024	$	298	$	298
4.3% due 2027		992		992
7.9% due 2029		463		463
7.3% due 2031		628		627
7.1% due 2033		537		537
6.0% due 2040		741		740
5.6% due 2041		1,235		1,234
5.8% due 2047		494		493
Total fixed-rate public notes		5,388		5,384
Capital lease obligations (a)		—		269
Financing obligations associated with floating production system (a)		—		40
Fair value adjustments - interest rate hedging		1		(2	)
Total Debt - Hess Corporation	$	5,389	$	5,691

Debt - Midstream:
Fixed-rate notes: 5.6% due 2026 - Hess Midstream Operations LP	$	787	$	—
Fixed-rate notes: 5.1% due 2028 - Hess Midstream Operations LP		540		—
Fixed-rate notes: 5.6% due 2026 - HIP		—		787
Term loan A facility - Hess Midstream Operations LP		394		—
Term loan A facility - HIP		—		194
Revolving credit facility - Hess Midstream Operations LP		32		—
Total Debt - Midstream	$	1,753	$	981

Total Debt:
Current maturities of long-term debt	$	—	$	67
Long-term debt		7,142		6,605
Total Debt	$	7,142	$	6,672

(a)	Upon adoption of ASC 842, Leases on January 1, 2019, capital lease and financing obligations previously included in Debt were reclassified to Finance leases.

At December 31, 2019, the maturity profile of total debt was as follows:

	Total			Hess Corporation			Midstream
	(In millions)
2020	$	—		$	—		$	—
2021		10			—			10
2022		20			—			20
2023		30			—			30
2024		672			300			372
Thereafter		6,488			5,138			1,350
Total Borrowings		7,220			5,438			1,782
Less: Deferred issuance costs		(78	)		(49	)		(29	)
Total Debt (excluding interest)	$	7,142		$	5,389		$	1,753

Debt – Hess Corporation:

Fixed-rate public notes:

At December 31, 2019, Hess Corporation’s fixed-rate public notes had a gross principal amount of $5,438 million (2018: $5,438 million) and a weighted average interest rate of 5.9% (2018: 5.9%). 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 $2,384 million of secured debt at December 31, 2019. Capitalized interest was $38 million in 2019 (2018: $20 million; 2017: $86 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. 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 an 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. No gain or loss was recognized from the sale transaction. The agreement is for 16 years with four consecutive twelve-month renewal options that may be exercised at our discretion. At December 31, 2018, the carrying value of the capital lease asset was $264 million and the carrying value of the capital lease obligation was $269 million, of which $15 million was included in Current maturities of long-term debt and $254 million was included in Long-term debt on our Consolidated Balance Sheet.

Credit facility:

In 2019, the Corporation entered into a new $3.5 billion revolving credit facility with a maturity date of May 15, 2023, which replaced the Corporation’s previous revolving credit facility that was scheduled to mature on January 21, 2021. The new facility can be used for borrowings and letters of credit. Borrowings on the new facility will generally bear interest at 1.30% above LIBOR, though the interest rate is subject to adjustment if the Corporation’s credit rating changes. The facility is subject to customary representations, warranties and covenants, including a financial covenant limiting the ratio of Total Consolidated Debt to Total Capitalization (as such terms are defined in the credit agreement for the facility) of the Corporation and its consolidated subsidiaries to 65%, and customary events of default. At December 31, 2019, 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:

	2019		2018
	(In millions)
Committed lines (a)	$	54	$	29
Uncommitted lines (a)		218		255
Total	$	272	$	284

(a)	At December 31, 2019, committed and uncommitted lines have expiration dates throughout 2020.

Debt - Midstream:

Senior unsecured notes:

In November 2017, HIP issued $800 million of 5.625% senior unsecured notes due in 2026. In December 2019, in connection with the acquisition of HIP and corporate restructuring described in Note 6, Hess Midstream, HESM Opco assumed $800 million of outstanding HIP senior notes in a par-for-par exchange. The senior notes are guaranteed by certain subsidiaries of HESM Opco.

In addition, in December 2019, HESM Opco issued $550 million of 5.125% senior unsecured notes due in 2028. The notes are guaranteed by HESM Opco’s direct and indirect wholly owned material domestic subsidiaries. Proceeds of the new notes were used to finance the acquisition of HIP and repay outstanding borrowings under HIP’s credit facilities.

Credit facilities:

Prior to the closing of the December 2019 transaction described in Note 6, Hess Midstream, HIP had a $600 million 5-year senior secured revolving credit facility and a $200 million senior secured Term Loan A facility, while Hess Midstream Partners LP had a $300 million 4-year senior secured syndicated revolving credit facility. In connection with the acquisition of HIP, both HIP and Hess Midstream Partners LP retired their existing senior secured revolving credit facilities and HESM Opco entered into a new 5-year senior secured syndicated revolving credit facility in the amount of $1.0 billion. HIP also retired its senior secured Term Loan A facility, which had borrowings of $190 million excluding deferred issuance costs, and HESM Opco entered into a fully drawn $400 million 5-year Term Loan A facility, receiving cash of $210 million at closing. The new revolving credit facility can be used for borrowings and letters of credit to fund HESM Opco’s operating activities, capital expenditures, distributions and for other general corporate purposes. Borrowings under the 5-year Term Loan A facility will generally bear interest at LIBOR plus an applicable margin ranging from 1.55% to 2.50%, while the applicable margin for the 5-year syndicated revolving credit facility ranges from 1.275% to 2.000%. Pricing levels for the facility fee and interest-rate margins are based on HESM Opco’s ratio of total debt to EBITDA as defined in the credit facilities. If HESM Opco obtains an investment grade credit rating, the pricing levels will be based on HESM Opco’s credit ratings in effect from time to time.

The credit facilities contain covenants that require HESM Opco to maintain a ratio of total debt to EBITDA for the prior four fiscal quarters of not greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to HESM Opco obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter. The credit facilities are secured by first-priority perfected liens on substantially all the presently owned and after-acquired assets of HESM Opco and its direct and indirect wholly owned material domestic subsidiaries, including equity interests directly owned by such entities, subject to certain customary exclusions. At December 31, 2019, borrowings of $32 million were drawn under HESM Opco’s revolving credit facility, and borrowings of $400 million, excluding deferred issuance costs, were drawn under HESM Opco’s Term Loan A facility. Borrowings under these credit facilities are non-recourse to Hess Corporation.

Leases - Supplemental Cash Flow Information Related to Leases (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($)
Cash paid for amounts included in the measurement of lease obligations:
Operating Leases, Operating cash flows	$ 419
Operating Leases, Financing cash flows	0
Finance Leases, Operating cash flows	21
Finance Leases, Financing cash flows	55
Noncash transactions:
Operating Leases, Leased assets recognized for new lease obligations incurred	14
Finance Leases, Leased assets recognized for new lease obligations incurred	$ 0

Retirement Plans - Fair Value of Financial Assets of Funded Pension Plans (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018 USD ($)
Level 3 \| Real Estate Funds \| Restatement Adjustment
Defined Benefit Plan Disclosure [Line Items]
Reclassification to NAV from previously presented value	$ 61

Subsequent Event - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsequent Event [Line Items]
Exploration expense for well costs		$ 233	$ 362	$ 507
Kosmos Energy Ltd \| Oldfield-1 Exploration Well in Gulf of Mexico
Subsequent Event [Line Items]
Exploration expense for well costs		$ 15
Scenario Forecast \| Kosmos Energy Ltd \| Oldfield-1 Exploration Well in Gulf of Mexico
Subsequent Event [Line Items]
Exploration expense for well costs	$ 15

Share-based Compensation - Summary of Restricted Stock Award Activity (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value of vested shares	$ 102	$ 54	$ 37

Retirement Plans - Components of Net Periodic Benefit Cost (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Net non-service pension (income) costs included in Other, net	$ 55	$ (61)	$ 14

Guarantees, Contingencies and Commitments - Schedule of Unconditional Purchase Obligations and Commitments (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Capital Expenditures
Loss Contingencies [Line Items]
Total	$ 1,743
2020	913
2021 and 2022	755
2023 and 2024	75
Thereafter	0
Operating Expenses
Loss Contingencies [Line Items]
Total	190
2020	158
2021 and 2022	20
2023 and 2024	9
Thereafter	3
Transportation and Related Contracts
Loss Contingencies [Line Items]
Total	1,009
2020	231
2021 and 2022	424
2023 and 2024	246
Thereafter	$ 108

Financial Risk Management Activities - Notional Amounts of Outstanding Financial Risk Management Derivative Contracts (Detail) MMBbls in Millions	Dec. 31, 2019 USD ($) MMBbls	Dec. 31, 2018 USD ($) MMBbls
Commodity
Derivative [Line Items]
Commodity - crude oil (millions of barrels) \| MMBbls	54.9	34.7
Foreign Exchange
Derivative [Line Items]
Outstanding gross notional amount	$ 90,000,000	$ 16,000,000
Interest Rate Swaps \| Designated as Fair Value Hedges
Derivative [Line Items]
Outstanding gross notional amount	$ 100,000,000	$ 100,000,000

Property, Plant and Equipment - Components of Property, Plant and Equipment (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Property Plant And Equipment [Line Items]
Total — at cost	$ 35,820	$ 33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment	19,006	17,139
Property, plant and equipment — net	16,814	16,083
Exploration and Production
Property Plant And Equipment [Line Items]
Unproved properties	168	394
Proved properties	3,304	3,124
Wells, equipment and related facilities	28,404	26,173
Total — at cost	31,876	29,691
Midstream
Property Plant And Equipment [Line Items]
Total — at cost	3,904	3,492
Corporate and Other
Property Plant And Equipment [Line Items]
Total — at cost	$ 40	$ 39

Debt - Additional Information (Detail) - USD ($)	12 Months Ended
Debt - Additional Information (Detail) - USD ($)	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Additional secured debt allowed to be borrowed	$ 2,384,000,000
Debt instrument redemption amount		$ 553,000,000
Loss on debt extinguishment	0	53,000,000	$ 0
Proceeds from asset sales	$ 22,000,000	607,000,000	3,296,000,000
Ratio of present value of future minimum lease payments to carrying value of lease obligation	100.00%
Letters of credit – Issued	$ 272,000,000	$ 284,000,000
Hess Corp - Revolving Credit Facility
Debt Instrument [Line Items]
Debt Instrument, undrawn borrowing capacity, amount	$ 3,500,000,000
Debt instrument maturity year	May 15, 2023
Revolving credit facility – Interest rate	1.30% above LIBOR
Interest rate applicable margin	1.30%
Debt instrument covenant, ratio	65.00%
Revolving credit facility - Outstanding amount	$ 0
Letters of credit – Issued	$ 0
Hess Corp - Previous Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility expiration date	Jan. 21, 2021
Floating, Storage and Offloading Vessel
Debt Instrument [Line Items]
North Malay Basin, offshore Peninsular Malaysia - Hess operated interest	50.00%	50.00%
Proceeds from asset sales		$ 260,000,000
Carrying value of lease asset		264,000,000
Capital leases carrying value		269,000,000
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
Other Debt
Debt Instrument [Line Items]
Carrying value of purchased debt		150,000,000
Hess Fixed-Rate Notes
Debt Instrument [Line Items]
Fixed-rate notes, gross principal amount	$ 5,438,000,000	$ 5,438,000,000
Weighted average interest rate - Hess Corp public notes	5.90%	5.90%
Capitalized interest	$ 38,000,000	$ 20,000,000	$ 86,000,000
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		2019
Amount of terminated interest rate swaps		$ 350,000,000

Guarantees, Contingencies and Commitments

12 Months Ended

Dec. 31, 2019

Commitments And Contingencies Disclosure [Abstract]

Guarantees, Contingencies and Commitments

17. 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.

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 agreed with the 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 the 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. Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected shipbuilding and repair facility adjacent to the Canal. The remedy selected by the EPA 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. The EPA’s original estimate was that this remedy would cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain. We have complied with the EPA’s March 2014 Administrative Order and contributed funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert. In January 2020, we received an additional Administrative Order from the EPA requiring us and several other parties to begin Remedial Action along the uppermost portion of the Canal. We intend to comply with this Administrative Order. The remediation work is anticipated to begin in the fourth quarter of 2020. The costs will continue to be allocated amongst the parties, as they were for the Remedial Design.

We periodically receive notices from the EPA that we are a “potential responsible party” under the Superfund legislation with respect to various waste disposal sites. Under this legislation, all potentially responsible parties may be jointly and severally liable. For any site for which we have received such a notice, the EPA’s claims or assertions of liability against us relating to these sites have not been fully developed, or the EPA’s claims have been settled or a settlement is under consideration, in all cases for amounts that are not material. The ultimate impact of these proceedings, and of any related proceedings by private parties, on our business or accounts cannot be predicted at this time due to the large number of other potentially responsible parties and the speculative nature of clean-up cost estimates, but is not expected to be material.

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 lawsuits, claims and proceedings, including the matters disclosed above, is not expected to have a material adverse effect on our financial condition, results of operations or cash flows. 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.

Unconditional Purchase Obligations and Commitments

The following table shows aggregate information for certain unconditional purchase obligations and commitments at December 31, 2019, which are not included elsewhere within these Consolidated Financial Statements:

			Payments Due by Period
					2021 and		2023 and
	Total		2020		2022		2024		Thereafter
	(In millions)
Capital expenditures	$	1,743	$	913	$	755	$	75	$	—
Operating expenses		190		158		20		9		3
Transportation and related contracts		1,009		231		424		246		108

Financial Risk Management Activities (Tables)

12 Months Ended

Dec. 31, 2019

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Financial Risk Management Derivative Contracts

The notional amounts of outstanding financial risk management derivative contracts were as follows:

	December 31, 2019		December 31, 2018
	(In millions)
Commodity - crude oil (millions of barrels)		54.9		34.7
Foreign exchange	$	90	$	16
Interest rate swaps	$	100	$	100

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, 2019
Derivative Contracts Designated as Hedging Instruments:
Commodity - Other current assets	$	125	$	—
Interest rate - Other assets (noncurrent)		1		—
Total derivative contracts designated as hedging instruments		126		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange		—		(1	)
Total derivative contracts not designated as hedging instruments		—		(1	)
Gross fair value of derivative contracts		126		(1	)
Master netting arrangements		—		—
Net Fair Value of Derivative Contracts	$	126	$	(1	)

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	)

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

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+ Details

Debt - Components of Debt (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 0	$ 67
Long-term debt	7,142	6,605
Total debt	7,142	6,672
Midstream
Debt Instrument [Line Items]
Total debt	1,753	981
Midstream \| Hess Midstream Operations LP
Debt Instrument [Line Items]
Term loan A facility	394	0
Midstream \| Hess Midstream Operations LP \| Revolving Credit Facility
Debt Instrument [Line Items]
Total Debt	32	0
Midstream \| Hess Infrastructure Partners (HIP)
Debt Instrument [Line Items]
Term loan A facility	0	194
Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	5,388	5,384
Capital lease obligations	0	269
Financing obligations associated with floating production system	0	40
Total debt	5,389	5,691
Hess Corporation \| Interest Rate Contract
Debt Instrument [Line Items]
Fair value adjustments - interest rate hedging	1	(2)
3.5% Due 2024 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	298	298
4.3% due 2027 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	992	992
7.9% Due 2029 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	463	463
7.3% Due 2031 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	628	627
7.1% Due 2033 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	537	537
6.0% Due 2040 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	741	740
5.6% Due 2041 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	1,235	1,234
5.8% Due 2047 \| Hess Corporation
Debt Instrument [Line Items]
Fixed-rate public notes	494	493
5.6% Due 2026 \| Midstream \| Hess Midstream Operations LP
Debt Instrument [Line Items]
Fixed-rate public notes	787	0
5.6% Due 2026 \| Midstream \| Hess Infrastructure Partners (HIP)
Debt Instrument [Line Items]
Fixed-rate public notes	0	787
5.1% Due 2028 \| Midstream \| Hess Midstream Operations LP
Debt Instrument [Line Items]
Fixed-rate public notes	$ 540	$ 0

Supplementary Cash Flow Information

12 Months Ended

Dec. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Supplementary Cash Flow Information

16. Supplementary Cash Flow Information

The following information supplements the Statement of Consolidated Cash Flows:

	2019			2018			2017
	(In millions)
Cash Flows From Operating Activities
Interest paid	$	(380	)	$	(394	)	$	(314	)
Net income taxes (paid) refunded		(417	)		(463	)		(210	)

Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P:
Capital expenditures incurred - E&P	$	(2,576	)	$	(1,909	)	$	(1,852	)
Increase (decrease) in related liabilities		143			55			64
Additions to property, plant and equipment - E&P	$	(2,433	)	$	(1,854	)	$	(1,788	)

Additions to property, plant and equipment - Midstream:
Capital expenditures incurred - Midstream	$	(416	)	$	(271	)	$	(121	)
Increase (decrease) in related liabilities		20			28			(28	)
Additions to property, plant and equipment - Midstream	$	(396	)	$	(243	)	$	(149	)

In December 2019, as part of HESM Opco’s acquisition of HIP (see Note 6, Hess Midstream), HESM Opco assumed $800 million of outstanding HIP notes (see Note 8, Debt).

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, 2019	Dec. 31, 2018	Dec. 31, 2017
Disposition Of Businesses [Line Items]
Income (Loss) from Continuing Operations Before Income Taxes Excluding Gain / Loss and Impairment	$ 221	$ 220	$ (5,778)
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	0	14
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	0	69
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	$ 0	$ (55)

Property, Plant and Equipment - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Capitalized Exploratory Well Costs [Line Items]
Charge to write-off previously capitalized exploratory wells	$ 0	$ 14	$ 268
Well costs incurred and expensed	49	$ 151	$ 0
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 400
Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	50.00%
Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage	28.00%
Capitalized well costs percentage	30.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage	50.00%
Capitalized well costs percentage	10.00%
North Malay Basin, Offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage	50.00%
Capitalized well costs percentage	10.00%
Nova Scotia, Offshore 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
Deepwater Tano/Cape Three Points license, Offshore Ghana
Capitalized Exploratory Well Costs [Line Items]
Project participation interest percentage			50.00%
Charge to write-off previously capitalized exploratory wells			$ 268

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate the Fair Value of Stock Options (Detail) - Stock Options - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	2.55%	2.74%	2.17%
Stock price volatility	0.359%	0.322%	0.333%
Dividend yield	1.76%	2.06%	1.96%
Expected life in years	6 years	6 years	6 years
Weighted average fair value per option granted	$ 18.08	$ 13.69	$ 14.51

Property, Plant and Equipment - Exploratory Drilling Costs Capitalized (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 400
Year 2018
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	157
Year 2017
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	73
Year 2016
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	0
Year 2015
Projects With Exploratory Well Costs Capitalized For More Than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	166
Year 2014 and prior
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

Nature of Operations, Basis of Presentation and Summary of Accounting Policies - Schedule of Impact of adoption on Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Assets
Property, plant and equipment — net	$ 16,814		$ 16,083
Operating lease right-of-use assets — net	447		0
Finance lease right-of-use assets — net	299		0
Liabilities
Accrued liabilities	1,803		1,560
Current maturities of long-term debt	0		67
Current portion of operating and finance lease obligations	199		0
Long-term debt	7,142		6,605
Long-term operating lease obligations	353		0
Long-term finance lease obligations	238		0
Other liabilities and deferred credits	$ 521		$ 575
ASC 842
Assets
Property, plant and equipment — net		$ 15,737
Operating lease right-of-use assets — net		804
Finance lease right-of-use assets — net		346
Liabilities
Accrued liabilities		1,558
Current maturities of long-term debt		12
Current portion of operating and finance lease obligations		437
Long-term debt		6,351
Long-term operating lease obligations		516
Long-term finance lease obligations		254
Other liabilities and deferred credits		483
ASC 842 \| Adjustment For Finance Leases
Assets
Property, plant and equipment — net		(346)
Operating lease right-of-use assets — net		0
Finance lease right-of-use assets — net		346
Liabilities
Accrued liabilities		0
Current maturities of long-term debt		(55)
Current portion of operating and finance lease obligations		55
Long-term debt		(254)
Long-term operating lease obligations		0
Long-term finance lease obligations		254
Other liabilities and deferred credits		0
ASC 842 \| Adjustment For Operating Leases
Assets
Property, plant and equipment — net		0
Operating lease right-of-use assets — net		804
Finance lease right-of-use assets — net		0
Liabilities
Accrued liabilities		(2)
Current maturities of long-term debt		0
Current portion of operating and finance lease obligations		382
Long-term debt		0
Long-term operating lease obligations		516
Long-term finance lease obligations		0
Other liabilities and deferred credits		$ (92)

Leases - Summary of Information Relates to Operating and Finance Leases Recorded (Detail)	12 Months Ended
	Dec. 31, 2019
Leases [Line Items]
Operating leases, Weighted average remaining lease term	5 years 4 months 24 days
Operating leases, Weighted average discount rate	4.30%
Finance leases, Weighted average remaining lease term	13 years 9 months 18 days
Finance leases, Range of remaining lease terms	13 years 9 months 18 days
Finance leases, Weighted average discount rate	7.90%
Minimum
Leases [Line Items]
Operating leases, Range of remaining lease terms	1 month 6 days
Maximum
Leases [Line Items]
Operating leases, Range of remaining lease terms	16 years 1 month 6 days

Debt - Midstream - Additional Information (Detail) - USD ($)		1 Months Ended	12 Months Ended
	Dec. 16, 2019	Nov. 30, 2017	Dec. 31, 2019
Hess Infrastructure Partners LP (HIP) \| Senior Secured Term Loan A Facility
Debt Instrument [Line Items]
Debt instrument face amount	$ 190,000,000
Hess Midstream Operations LP
Debt Instrument [Line Items]
Debt instrument covenant, description			The credit facilities contain covenants that require HESM Opco to maintain a ratio of total debt to EBITDA for the prior four fiscal quarters of not greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to HESM Opco obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter.
Ratio of debt to EBITDA ratio for prior four fiscal quarter - Maximum			500.00%
Ratio of debt to EBITDA ratio for period after acquisitions - Maximum			550.00%
Secured leverage ratio - Maximum			400.00%
Hess Midstream Operations LP \| 5-Year Senior Secured Syndicated Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument face amount			$ 1,000,000,000.0
Term of facility - Term			5 years
Hess Midstream Operations LP \| 5-year Term Loan A facility
Debt Instrument [Line Items]
Term of facility - Term			5 years
Revolving credit facility – Interest rate			LIBOR plus an applicable margin ranging from 1.55% to 2.50%
Hess Midstream Operations LP \| 5-year Term Loan A facility \| Minimum
Debt Instrument [Line Items]
Interest rate applicable margin			1.55%
Hess Midstream Operations LP \| 5-year Term Loan A facility \| Maximum
Debt Instrument [Line Items]
Interest rate applicable margin			2.50%
Hess Midstream Operations LP \| 5-Year Syndicated Revolving Credit Facility \| Minimum
Debt Instrument [Line Items]
Interest rate applicable margin			1.275%
Hess Midstream Operations LP \| 5-Year Syndicated Revolving Credit Facility \| Maximum
Debt Instrument [Line Items]
Interest rate applicable margin			2.00%
Hess Midstream Operations LP \| Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 32,000,000
Hess Midstream Operations LP \| Term Loan A Facility
Debt Instrument [Line Items]
Maximum borrowing capacity			400,000,000
Hess Infrastructure Partners (HIP) \| 5-Year Senior Secured Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 600,000,000
Term of facility - Term	5 years
Hess Infrastructure Partners (HIP) \| Senior Secured Term Loan A Facility
Debt Instrument [Line Items]
Debt instrument face amount	$ 200,000,000
Hess Midstream Partners LP (Hess Midstream Partners) \| 4-Year Senior Secured Syndicated Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 300,000,000
Term of facility - Term			4 years
Hess Midstream Partners LP (Hess Midstream Partners) \| 5-year Term Loan A facility
Debt Instrument [Line Items]
Debt instrument face amount			$ 400,000,000
Cash received			210,000,000
Midstream \| Hess Infrastructure Partners LP (HIP)
Debt Instrument [Line Items]
Debt instrument face amount	$ 800,000,000		800,000,000
5.625% Senior Notes Due in 2026 \| Midstream \| Hess Infrastructure Partners LP (HIP)
Debt Instrument [Line Items]
Debt instrument face amount		$ 800,000,000
Debt instrument interest rate		5.625%
Debt instrument maturity year		2026
5.125% senior unsecured notes due in 2028 \| Midstream \| Hess Midstream Operations LP
Debt Instrument [Line Items]
Debt instrument face amount			$ 550,000,000
Debt instrument interest rate			5.125%
Debt instrument maturity year			2028

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Valuation Allowance, Deferred Tax Asset, Decrease, Amount	$ (143)	$ (322)	$ (251)

Share-based Compensation

12 Months Ended

Dec. 31, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Share-based Compensation

11. Share-based Compensation

We have established and maintain long term incentive plans (LTIP) for the granting of restricted common shares (Restricted stock), PSUs and stock options to our employees. At December 31, 2019, the total number of authorized common stock under the LTIP was 51.5 million shares, of which we have 16.4 million shares available for issuance. Share‑based compensation expense consisted of the following:

	2019		2018		2017
	(In millions)
Restricted stock	$	53	$	40	$	56
Stock options		10		10		9
Performance share units		22		22		21
Share-based compensation expense before income taxes	$	85	$	72	$	86
Income tax benefit on share-based compensation expense	$	—	$	—	$	1

Based on share‑based compensation awards outstanding at December 31, 2019, unearned compensation expense, before income taxes, will be recognized in future years as follows (in millions): 2020: $53, 2021: $29 and 2022: $4.

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 2019:

		Shares of Restricted Common Stock			Weighted - Average Price on Date of Grant
	(In thousands, except per share amounts)
Outstanding at January 1, 2019			2,881		$	48.70
Granted			965			56.87
Vested (a)			(1,742	)		47.35
Forfeited			(90	)		52.67
Outstanding at December 31, 2019			2,014		$	53.61

(a)

In 2019, restricted stock with fair values of $102 million were vested (2018: $54 million; 2017: $37 million).

PSUs:

PSUs generally vest three years from the date of grant and are valued using a Monte Carlo simulation 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 2019:

	Performance Share Units			Weighted - Average Fair Value on Date of Grant
	(In thousands, except per share amounts)
Outstanding at January 1, 2019		1,063		$	53.98
Granted		269			68.87
Vested (a)		(391	)		51.00
Forfeited		(12	)		52.05
Outstanding at December 31, 2019		929		$	59.57

(a)

In 2019, PSU’s with fair value of $16 million were vested (2018: $9 million; 2017: $10 million).

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

	2019			2018			2017
Risk free interest rate		2.48	%		2.39	%		1.55	%
Stock price volatility		0.369			0.400			0.387
Contractual term in years		3.0			3.0			3.0
Grant date price of Hess common stock	$	56.74		$	48.48		$	51.03

Stock options:

Stock options vest over three years from the date of grant, have a 10‑year term, and the exercise price equals the market price of our common stock on the date of grant. The following is a summary of stock options activity in 2019:

	Number of options (In thousands)			Weighted Average Exercise Price per Share		Weighted Average Remaining Contractual Term
Outstanding at January 1, 2019		5,170		$	61.91	4.3 years
Granted		527			56.74
Exercised		(744	)		54.23
Forfeited		(652	)		57.69
Outstanding at December 31, 2019		4,301		$	63.24	4.8 years

At December 31, 2019, there were 4.3 million outstanding stock options (3.1 million exercisable) with a weighted average remaining contractual life of 4.8 years (3.4 years for exercisable options) and an aggregated intrinsic value of $39 million ($22 million for exercisable options).

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

	2019			2018			2017
Risk free interest rate		2.55	%		2.74	%		2.17	%
Stock price volatility		0.359			0.322		0.333
Dividend yield		1.76	%		2.06	%		1.96	%
Expected life in years		6.0			6.0			6.0
Weighted average fair value per option granted	$	18.08		$	13.69		$	14.51

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.

Retirement Plans - Actuarial Assumptions Used for Pension Plans & Postretirement Medical Plan (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plans
Benefit Obligations:
Discount rate	2.90%	3.90%	3.30%
Rate of compensation increase	3.80%	3.80%	4.50%
Net Periodic Benefit Cost:
Discount rate, Service cost	3.90%	3.90%	3.70%
Discount rate, Interest cost	3.40%	3.30%	3.70%
Expected return on plan assets	7.10%	7.20%	7.30%
Rate of compensation increase	3.80%	4.50%	4.60%
Postretirement Medical Plan
Benefit Obligations:
Discount rate	2.80%	3.90%	3.20%
Initial health care trend rate	6.50%	6.90%	7.30%
Ultimate trend rate	4.50%	4.50%	4.50%
Year in which ultimate trend rate is reached	2038	2038	2038

Segment Information - Additional Information (Detail)	12 Months Ended
Segment Information - Additional Information (Detail)	Dec. 31, 2019 Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	2

Outstanding and Weighted Average Common Shares - 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, 2019	Dec. 31, 2018	Dec. 31, 2017
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Net Income (Loss)	$ (240)	$ (115)	$ (3,941)
Less: Net income (loss) attributable to noncontrolling interests	168	167	133
Less: Preferred stock dividends	4	46	46
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (412)	$ (328)	$ (4,120)
Weighted Average Number of Common Shares Outstanding:
Shares outstanding – Basic	301.2	298.2	314.1
Diluted	301.2	298.2	314.1
Basic	$ (1.37)	$ (1.10)	$ (13.12)
Diluted	$ (1.37)	$ (1.10)	$ (13.12)
Restricted Common Stock
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	2.2	2.9	3.3
Stock Options
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	4.7	5.5	6.4
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	1.7	1.1	0.6
Common Shares from Conversion of Preferred Stocks
Weighted Average Number of Common Shares Outstanding:
Antidilutive shares excluded from computation of diluted shares	0.0	12.7	12.8
Restricted Common Stock
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Stock Options
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Performance Share Units
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0
Mandatory Convertible Preferred Stock
Weighted Average Number of Common Shares Outstanding:
Effect of dilutive securities	0.0	0.0	0.0

Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt	$ 7,142
Carrying value
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt	7,142
Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt fair value	$ 8,242

Share-based Compensation - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of authorized common stock shares under LTIP	51,500,000
Number of shares under LTIP, available for issuance of restricted common shares, performance share units and stock options	16,400,000
Unearned compensation expense, before income taxes due 2020	$ 53
Unearned compensation expense, before income taxes due 2021	29
Unearned compensation expense, before income taxes due 2022	$ 4
Performance of predetermined peer companies	3 years
Outstanding stock options	4,300,000
Number of stock options, exercisable	3,100,000
Weighted average remaining contractual term - Outstanding	4 years 9 months 18 days
Weighted average remaining contractual life for options, exercisable	3 years 4 months 24 days
Aggregated intrinsic value	$ 39
Aggregated intrinsic value for exercisable options	$ 22
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%
PSU awards, fair value assumption method used	Monte Carlo simulation
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	4,301,000	5,170,000
Weighted average remaining contractual term - Outstanding	4 years 9 months 18 days	4 years 3 months 18 days

Share-based Compensation - Summary of Stock Option Activity (Detail) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Exercised	(700)	(600)	(200)
Options - Outstanding at end of period	4,300
Weighted average remaining contractual term - Outstanding	4 years 9 months 18 days
Stock Options
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options - Outstanding at beginning of period	5,170
Options - Granted	527
Options - Exercised	(744)
Options - Forfeited	(652)
Options - Outstanding at end of period	4,301	5,170
Weighted average exercise price per share - Outstanding at beginning of period	$ 61.91
Weighted average exercise price per share - Granted	56.74
Weighted average exercise price per share - Exercised	54.23
Weighted average exercise price per share - Forfeited	57.69
Weighted average exercise price per share - Outstanding at end of period	$ 63.24	$ 61.91
Weighted average remaining contractual term - Outstanding	4 years 9 months 18 days	4 years 3 months 18 days

Hess Midstream

12 Months Ended

Dec. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Hess Midstream

6. Hess Midstream

Prior to December 16, 2019, the Midstream segment was primarily comprised of HIP, a 50/50 joint venture between Hess Corporation and Global Infrastructure Partners (GIP), formed to own, operate, develop and acquire a diverse set of midstream assets to provide fee-based services to Hess and third-party customers. HIP was initially formed on May 21, 2015, with Hess selling 50% of HIP to GIP for approximately $2.6 billion on July 1, 2015.

On April 10, 2017, HIP completed an initial public offering (IPO) of 16,997,000 common units, representing 30.5% limited partnership interests in its subsidiary Hess Midstream Partners LP (Hess Midstream Partners), for net proceeds of approximately $365.5 million. In connection with the IPO, HIP contributed a 20% controlling economic interest in each of Hess North Dakota Pipeline Operations LP, Hess TGP Operations LP, and Hess North Dakota Export Logistics Operations LP, and a 100% economic interest in Hess Mentor Storage Holdings LLC (collectively the “Contributed Businesses”). In exchange for the contributed businesses, Hess and GIP each received common and subordinated units representing a direct 33.75% limited partner interest in Hess Midstream Partners and a 50% indirect ownership interest through HIP in Hess Midstream Partners’ general partner, which had a 2% economic interest in Hess Midstream Partners plus incentive distribution rights.

On March 1, 2019, HIP acquired Hess’s existing Bakken water services business for $225 million in cash. As a result of this transaction between entities under common control, we recorded an after-tax gain of $78 million in additional paid-in capital with an offsetting reduction to noncontrolling interest to reflect the adjustment to GIP’s noncontrolling interest in HIP. On March 22, 2019, HIP and Hess Midstream Partners acquired crude oil and gas gathering assets, and HIP acquired water gathering assets of Summit Midstream Partners LP’s Tioga Gathering System for aggregate cash consideration of approximately $90 million, with the potential for an additional $10 million of contingent payments in future periods subject to certain future performance metrics. On January 25, 2018, Hess Midstream Partners entered into a 50/50 joint venture with Targa Resources Corp. to construct a new 200 million standard cubic feet per day gas processing plant called Little Missouri 4. The plant, which is operated by Targa, was placed into service in the third quarter of 2019.

On December 16, 2019, Hess Midstream Partners acquired HIP, including HIP’s 80% interest in Hess Midstream Partners’ oil and gas midstream assets, HIP’s water services business and the outstanding economic general partner interest and incentive distribution rights in Hess Midstream Partners LP. In addition, Hess Midstream Partners’ organizational structure converted from a master limited partnership into an “Up-C” structure in which Hess Midstream Partners’ public unitholders received newly issued Class A shares in a new public entity named Hess Midstream LP (Hess Midstream), which is taxed as a corporation for U.S. Federal and State income tax purposes. Hess Midstream Partners changed its name to “Hess Midstream Operations LP” (HESM Opco) and became a consolidated subsidiary of Hess Midstream, the new publicly listed entity. As consideration for the acquisition, we received a cash payment of $301 million and approximately 115 million newly issued HESM Opco Class B units. After giving effect to the acquisition and related transactions, public shareholders of Class A shares in Hess Midstream own 6% of the consolidated entity on an as-exchanged basis and Hess and GIP each own 47% of the consolidated entity on an as-exchanged basis, primarily through the sponsors’ ownership of Class B units in HESM Opco that are exchangeable into Class A shares of Hess Midstream on a one-for-one basis, or referred to as “Hess Corporation’s 47% consolidated ownership in Hess Midstream LP”.

At December 31, 2019, Hess Midstream liabilities totaling $1,941 million are on a nonrecourse basis to Hess Corporation, while Hess Midstream assets available to settle the obligations of Hess Midstream included Cash and cash equivalents totaling $3 million and Property, plant and equipment, net totaling $3,010 million. At December 31, 2018, HIP liabilities totaling $1,105 million were 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 and Property, plant and equipment, net totaling $2,664 million.

Share-based Compensation - Share-based Compensation Activity (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 85	$ 72	$ 86
Income tax benefit on share-based compensation expense		0	1
Restricted Stock
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	53	40	56
Stock Options
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	10	10	9
Performance Share Units
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense before income taxes	$ 22	$ 22	$ 21

Retirement Plans - Components of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Settlement loss		$ 93	$ 4	$ 19
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost		44	42	49
Interest cost		89	91	102
Expected return on plan assets		(180)	(194)	(168)
Amortization of unrecognized net actuarial losses (gains)		52	39	58
Settlement loss	$ 88	93	4	19
Curtailment gain		0	0	0
Net Periodic Benefit Cost		98	(18)	60
Postretirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost		2	2	4
Interest cost		2	3	3
Expected return on plan assets		0	0	0
Amortization of unrecognized net actuarial losses (gains)		(1)	(2)	0
Settlement loss		0	0	0
Curtailment gain		0	(2)	0
Net Periodic Benefit Cost		$ 3	$ 1	$ 7

Income Taxes

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Income Taxes

14. Income Taxes

The provision (benefit) for income taxes consisted of:

	2019			2018			2017
	(In millions)
United States
Federal
Current	$	(1	)	$	1		$	(23	)
Deferred taxes and other accruals		72			(74	)		(6	)
State		16			(45	)		—
		87			(118	)		(29	)
Foreign
Current (a)		447			455			179
Deferred taxes and other accruals		(73	)		(2	)		(1,987	)
		374			453			(1,808	)
Total Provision (Benefit) For Income Taxes	$	461		$	335		$	(1,837	)

(a)	Primarily comprised of Libya in 2019, 2018 and 2017.

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

	2019			2018			2017
	(In millions)
United States (a)	$	(338	)	$	(219	)	$	(2,784	)
Foreign		559			439			(2,994	)
Total Income (Loss) Before Income Taxes	$	221		$	220		$	(5,778	)

(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:

	2019				2018				2017
U.S. statutory rate		21.0		%		21.0		%		35.0		%
Effect of foreign operations (a)		142.9				141.2				17.4
State income taxes, net of Federal income tax		5.8				(18.9	)			—
Change in enacted tax laws (b)		—				—				(23.6	)
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	)
Valuation allowance on current year operations		41.8				55.2				(14.9	)
Valuation allowance against previously benefited deferred tax assets		—				—				0.1
Release valuation allowance against previously unbenefited deferred tax assets		(24.5	)			—				—
Noncontrolling interests in Midstream		(16.0	)			(15.9	)			0.8
Intraperiod allocation		33.7				(37.3	)			—
Equity and executive compensation		2.2				7.4				(0.3	)
Other		1.2				(0.3	)			—
Total		208.1		%		152.4		%		31.8		%

(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:

	2019			2018
	(In millions)
Deferred Tax Liabilities
Property, plant and equipment and investments	$	(1,318	)	$	(853	)
Other		(45	)		(77	)
Total Deferred Tax Liabilities		(1,363	)		(930	)
Deferred Tax Assets
Net operating loss carryforwards		4,733			4,239
Tax credit carryforwards		66			134
Property, plant and equipment and investments		206			416
Accrued compensation, deferred credits and other liabilities		179			232
Asset retirement obligations		261			225
Other		317			161
Total Deferred Tax Assets		5,762			5,407
Valuation allowances (a)		(4,734	)		(4,877	)
Total deferred tax assets, net of valuation allowances		1,028			530
Net Deferred Tax Assets (Liabilities)	$	(335	)	$	(400	)

(a)	In 2019, the valuation allowance decreased by $143 million (2018: decrease of $322 million; 2017: decrease of $251 million).

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

	2019			2018
	(In millions)
Deferred income taxes (long-term asset)	$	80		$	21
Deferred income taxes (long-term liability)		(415	)		(421	)
Net Deferred Tax Assets (Liabilities)	$	(335	)	$	(400	)

At December 31, 2019, we have recognized a gross deferred tax asset related to net operating loss carryforwards of $4,733 million before application of valuation allowances. The deferred tax asset is comprised of $1,447 million attributable to foreign net operating losses which begin to expire in 2025, $2,746 million attributable to U.S. Federal operating losses which begin to expire in 2034, and $540 million attributable to losses in various U.S. states which begin to expire in 2020. The deferred tax asset attributable to foreign net operating losses, net of valuation allowances, is $110 million. A full valuation allowance is established against the deferred tax asset attributable to U.S. Federal and state net operating losses. At December 31, 2019, we have U.S. Federal, state and foreign alternative minimum tax credit carryforwards of $49 million, which can be carried forward indefinitely, and approximately $15 million of other business credit carryforwards. The deferred tax asset attributable to these credits, net of valuation allowances was not significant. A full valuation allowance is established against our foreign tax credit carryforwards of $3 million, which begin to expire in 2021.

At December 31, 2019, the Balance Sheet reflects a $4,734 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 (until December 2019). 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, 2019 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. At December 31, 2019 the valuation allowance established against the net deferred tax asset in Guyana for the Stabroek Block was released as a result of the positive evidence from first production in December 2019, and the significant forecasted pre-tax income from operations. The cumulative pre-tax losses in Guyana were driven by pre-production activities.

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

	2019			2018			2017
	(In millions)
Balance at January 1	$	168		$	205		$	424
Additions based on tax positions taken in the current year		2			19			14
Additions based on tax positions of prior years		1			36			4
Reductions based on tax positions of prior years		(1	)		(78	)		(147	)
Reductions due to settlements with taxing authorities		—			(10	)		(85	)
Reductions due to lapses in statutes of limitation		(2	)		(4	)		(5	)
Balance at December 31	$	168		$	168		$	205

The December 31, 2019 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 $4 million and $11 million due to settlements with taxing authorities or other resolutions, as well as lapses in statutes of limitation. At December 31, 2019, our accrued interest and penalties related to unrecognized tax benefits is $7 million (2018: $3 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 2011.

Share-based Compensation - Summary of PSU Activity (Detail) - Performance Share Units shares in Thousands	12 Months Ended
	Dec. 31, 2019 $ / shares shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards - Outstanding at beginning of period \| shares	1,063
Awards - Granted \| shares	269
Awards - Vested \| shares	(391)
Awards - Forfeited \| shares	(12)
Awards - Outstanding at end of period \| shares	929
Weighted average fair value on date of grant - Outstanding at beginning of period \| $ / shares	$ 53.98
Weighted average fair value on date of grant - Granted \| $ / shares	68.87
Weighted average fair value on date of grant - Vested \| $ / shares	51.00
Weighted average fair value on date of grant - Forfeited \| $ / shares	52.05
Weighted average fair value on date of grant - Outstanding at end of period \| $ / shares	$ 59.57

Leases

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Leases

7. Leases

We determine if an arrangement is a lease at inception by evaluating whether the contract conveys the right to control an identified asset during the period of use. ROU assets represent our right to use an identified asset for the lease term and lease obligations represent our obligation to make payments as set forth in the lease arrangement. ROU assets and lease liabilities are recognized in the Consolidated Balance Sheet as operating leases or finance leases at the commencement date based on the present value of the minimum lease payments over the lease term. Where the implicit discount rate in a lease is not readily determinable, we use our incremental borrowing rate based on information available at the commencement date for determining the present value of the minimum lease payments. The lease term used in measurement of our lease obligations includes options to extend or terminate the lease when, in our judgment, it is reasonably certain that we will exercise that option. Variable lease payments that depend on an index or a rate are included in the measurement of lease obligations using the index or rate at the commencement date. Variable lease payments that vary because of changes in facts or circumstances after the commencement date of the lease are not included in the minimum lease payments used to measure lease obligations. We have agreements that include financial obligations for lease and nonlease components. For purposes of measuring lease obligations, we have elected not to separate nonlease components from lease components for the following classes of assets: drilling rigs, office space, offshore vessels, and aircraft. We apply a portfolio approach to account for operating lease ROU assets and liabilities for certain vehicles, railcars, field equipment and office equipment leases.

Finance lease cost is recognized as amortization of the ROU asset and interest expense on the lease liability. Operating lease cost is generally recognized on a straight-line basis. Operating lease costs for drilling rigs used to drill development wells and successful exploration wells are capitalized. Operating lease cost for other ROU assets used in oil and gas producing activities are either capitalized or expensed on a straight-line basis based on the nature of operation for which the ROU asset is utilized.

Leases with an initial term of 12 months or less are not recorded on the balance sheet as permitted under ASC 842. We recognize lease cost for short-term leases on a straight-line basis over the term of the lease. Some of our leases include one or more options to renew. The renewal option is at our sole discretion and is not included in the lease term for measurement of the lease obligation unless we are reasonably certain, at the commencement date of the lease, to renew the lease.

Operating and finance leases presented on the Consolidated Balance Sheet at December 31, 2019 were as follows:

	Operating Leases		Finance Leases
	(In millions)
Right-of-use assets — net (a)	$	447	$	299
Lease obligations:
Current	$	182	$	17
Long-term		353		238
Total lease obligations	$	535	$	255

(a)	Finance lease ROU assets have a cost of $381 million and accumulated amortization of $82 million.

Lease obligations represent 100% of the present value of future minimum lease payments in the lease arrangement. Where we have contracted directly with a lessor in our role as operator of an unincorporated oil and gas venture, we bill our partners their proportionate share for reimbursements as payments under lease agreements become due pursuant to the terms of our joint operating and other agreements.

The nature of our leasing arrangements at December 31, 2019 was as follows:

Operating leases: In the normal course of business, we primarily lease drilling rigs, equipment, logistical assets (offshore vessels, aircraft, and shorebases), and office space.

Finance leases: In 2018, as detailed in Note 8, Debt, 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%). The remaining lease term utilized in the lease obligation is 13.8 years.

Maturities of lease obligations at December 31, 2019 were as follows:

	Operating Leases			Finance Leases
	(In millions)
2020	$	200		$	36
2021		72			36
2022		65			36
2023		64			36
2024		65			36
Remaining years		133			212
Total lease payments		599			392
Less: Imputed interest		(64	)		(137	)
Total lease obligations	$	535		$	255

The following information relates to the Operating and Finance leases recorded at December 31, 2019:

	Operating Leases	Finance Leases
Weighted average remaining lease term	5.4 years	13.8 years
Range of remaining lease terms	0.1 - 16.1 years	13.8 years
Weighted average discount rate	4.3%	7.9%

The components of lease costs for the year ended December 31, 2019 were as follows (in millions):

Operating lease cost	$	414
Finance lease cost:
Amortization of leased assets		43
Interest on lease obligations		21
Short-term lease cost (a)		164
Variable lease cost (b)		89
Sublease income (c)		(12	)
Total lease cost (d)	$	719

(a)	Short-term lease cost is primarily attributable to equipment used in global exploration, development, and production activities. Future short-term lease costs will vary based on activity levels of our operated assets.

(b)

Variable lease costs for the drilling rig leases result from differences in the minimum rate and the actual usage of the ROU asset during the lease period. Variable lease costs for logistical assets result from differences in stated monthly rates and total charges reflecting the actual usage of the ROU asset during the lease period. Variable lease costs for our office leases represent common area maintenance charges which have not been separated from lease components.

(c)	We sublease certain of our office space to third parties under our head lease.

(d)	Prior to the adoption of ASC 842, we incurred total rental expense of $154 million in 2018 (2017: $123 million) and income from subleases of $8 million (2017: $10 million).

The above lease costs represent 100% of the lease payments due for the period, including where we as operator have contracted directly with suppliers. As the payments under lease agreements where we are operator become due, we bill our partners their proportionate share for reimbursement pursuant to the terms of our joint operating agreements. Reimbursements are not reflected in the table above. Certain lease costs above associated with exploration and development activities are included in capital expenditures.

Supplemental cash flow information related to leases for the year ended December 31, 2019 was as follows:

	Operating Leases		Finance Leases
	(In millions)
Cash paid for amounts included in the measurement of lease obligations:
Operating cash flows (a)	$	419	$	21
Financing cash flows (a)		—		55
Noncash transactions:
Leased assets recognized for new lease obligations incurred	14			—

(a)	Amounts represent gross lease payments before any recovery from partners.

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, 2019	Dec. 31, 2018	Dec. 31, 2017
Change in Fair Value of Plan Assets
Beginning balance	$ 2,568
Ending balance	2,732	$ 2,568
Funded Pension Plans
Change in Benefit Obligation
Beginning balance	2,492	2,765
Service cost	33	30
Interest cost	82	84
Actuarial (gains) loss	401	(237)
Single premium annuity contract payment	(249)	0
Benefit payments	(113)	(110)
Plan curtailments	0	(10)
Plan amendments	0	4
Foreign currency exchange rate changes	21	(34)
Ending balance	2,667	2,492	$ 2,765
Change in Fair Value of Plan Assets
Beginning balance	2,568	2,732
Actual return on plan assets	462	(77)
Employer contributions	40	59
Single premium annuity contract payment	(249)	0
Benefit payments	(113)	(110)
Foreign currency exchange rate changes	24	(36)
Ending balance	2,732	2,568	2,732
Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	65	76
Unrecognized Net Actuarial (Gains) Losses	756	778
Postretirement Medical Plan
Change in Benefit Obligation
Beginning balance	59	87
Service cost	2	2	4
Interest cost	2	3	3
Actuarial (gains) loss	19	(24)
Single premium annuity contract payment	0	0
Benefit payments	(7)	(7)
Plan curtailments	0	(2)
Plan amendments	0	0
Foreign currency exchange rate changes	0	0
Ending balance	75	59	87
Change in Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	7	7
Single premium annuity contract payment	0	0
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,	(75)	(59)
Unrecognized Net Actuarial (Gains) Losses	(12)	(32)
Unfunded Pension Plan
Change in Benefit Obligation
Beginning balance	216	249
Service cost	11	12
Interest cost	7	7
Actuarial (gains) loss	22	(29)
Single premium annuity contract payment	0	0
Benefit payments	(14)	(19)
Plan curtailments	0	(4)
Plan amendments	0	0
Foreign currency exchange rate changes	0	0
Ending balance	242	216	249
Change in Fair Value of Plan Assets
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	14	19
Single premium annuity contract payment	0	0
Benefit payments	(14)	(19)
Foreign currency exchange rate changes	0	0
Ending balance	0	0	$ 0
Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	(242)	(216)
Unrecognized Net Actuarial (Gains) Losses	$ 65	$ 47

Outstanding and Weighted Average Common Shares - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended												12 Months Ended
	Jan. 31, 2019	Feb. 29, 2016	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	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, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Class Of Stock [Line Items]
Series A, cumulative mandatory convertible preferred stock - dividend rate															8.00%	8.00%
Preferred stock, par value			$ 1.00				$ 1.00								$ 1.00	$ 1.00
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															0	25,200,000	2,600,000
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	$ 1.00	$ 1.00	$ 1.00
Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Shares of stock issued		575,000
Series A, cumulative mandatory convertible preferred stock - dividend rate		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 \| Minimum
Class Of Stock [Line Items]
Number of shares issued for each share of 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 preferred stock that is converted		25.642
Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Number of shares issued for each share of preferred stock that is converted			21.822												21.822
Common stock issuance following preferred stock conversion	12,500,000														12,500,000
Number of common shares received from capped call upon conversion of preferred stocks	900,000														900,000
Net number of common shares issued upon conversion of preferred stocks	11,600,000														11,600,000
Common Stock
Class Of Stock [Line Items]
Shares of stock issued		28,750,000
Common stock repurchased, share repurchase program																$ 25	$ 3

Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($) Well	Dec. 31, 2018 USD ($) Well	Dec. 31, 2017 USD ($) Well
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 418	$ 304	$ 597
Additions to capitalized exploratory well costs pending the determination of proved reserves	224	128	116
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(58)	0	(165)
Capitalized exploratory well costs charged to expense	0	(14)	(268)
Dispositions and other	0	0	24
Ending balance	$ 584	$ 418	$ 304
Number of Wells at December 31 \| Well	31	24	12

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Components of Income Tax Provision (Benefit)

The provision (benefit) for income taxes consisted of:

	2019			2018			2017
	(In millions)
United States
Federal
Current	$	(1	)	$	1		$	(23	)
Deferred taxes and other accruals		72			(74	)		(6	)
State		16			(45	)		—
		87			(118	)		(29	)
Foreign
Current (a)		447			455			179
Deferred taxes and other accruals		(73	)		(2	)		(1,987	)
		374			453			(1,808	)
Total Provision (Benefit) For Income Taxes	$	461		$	335		$	(1,837	)

(a)	Primarily comprised of Libya in 2019, 2018 and 2017.

Income (Loss) Before Income Taxes

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

	2019			2018			2017
	(In millions)
United States (a)	$	(338	)	$	(219	)	$	(2,784	)
Foreign		559			439			(2,994	)
Total Income (Loss) Before Income Taxes	$	221		$	220		$	(5,778	)

(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:

	2019				2018				2017
U.S. statutory rate		21.0		%		21.0		%		35.0		%
Effect of foreign operations (a)		142.9				141.2				17.4
State income taxes, net of Federal income tax		5.8				(18.9	)			—
Change in enacted tax laws (b)		—				—				(23.6	)
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	)
Valuation allowance on current year operations		41.8				55.2				(14.9	)
Valuation allowance against previously benefited deferred tax assets		—				—				0.1
Release valuation allowance against previously unbenefited deferred tax assets		(24.5	)			—				—
Noncontrolling interests in Midstream		(16.0	)			(15.9	)			0.8
Intraperiod allocation		33.7				(37.3	)			—
Equity and executive compensation		2.2				7.4				(0.3	)
Other		1.2				(0.3	)			—
Total		208.1		%		152.4		%		31.8		%

(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)

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:

	2019			2018
	(In millions)
Deferred Tax Liabilities
Property, plant and equipment and investments	$	(1,318	)	$	(853	)
Other		(45	)		(77	)
Total Deferred Tax Liabilities		(1,363	)		(930	)
Deferred Tax Assets
Net operating loss carryforwards		4,733			4,239
Tax credit carryforwards		66			134
Property, plant and equipment and investments		206			416
Accrued compensation, deferred credits and other liabilities		179			232
Asset retirement obligations		261			225
Other		317			161
Total Deferred Tax Assets		5,762			5,407
Valuation allowances (a)		(4,734	)		(4,877	)
Total deferred tax assets, net of valuation allowances		1,028			530
Net Deferred Tax Assets (Liabilities)	$	(335	)	$	(400	)

(a)	In 2019, the valuation allowance decreased by $143 million (2018: decrease of $322 million; 2017: decrease of $251 million).

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

	2019			2018
	(In millions)
Deferred income taxes (long-term asset)	$	80		$	21
Deferred income taxes (long-term liability)		(415	)		(421	)
Net Deferred Tax Assets (Liabilities)	$	(335	)	$	(400	)

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:

	2019			2018			2017
	(In millions)
Balance at January 1	$	168		$	205		$	424
Additions based on tax positions taken in the current year		2			19			14
Additions based on tax positions of prior years		1			36			4
Reductions based on tax positions of prior years		(1	)		(78	)		(147	)
Reductions due to settlements with taxing authorities		—			(10	)		(85	)
Reductions due to lapses in statutes of limitation		(2	)		(4	)		(5	)
Balance at December 31	$	168		$	168		$	205

Income Taxes - Components of Deferred Tax Liabilities and Deferred Tax Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Deferred Tax Liabilities
Property, plant and equipment and investments	$ (1,318)	$ (853)
Other	(45)	(77)
Total Deferred Tax Liabilities	(1,363)	(930)
Deferred Tax Assets
Net operating loss carryforwards	4,733	4,239
Tax credit carryforwards	66	134
Property, plant and equipment and investments	206	416
Accrued compensation, deferred credits and other liabilities	179	232
Asset retirement obligations	261	225
Other	317	161
Total Deferred Tax Assets	5,762	5,407
Valuation allowances	(4,734)	(4,877)
Total deferred tax assets, net of valuation allowances	1,028	530
Net Deferred Tax Assets (Liabilities)	$ (335)	$ (400)

Leases (Tables)

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Schedule of Balance Sheet Information Related to Operating and Finance Leases

Operating and finance leases presented on the Consolidated Balance Sheet at December 31, 2019 were as follows:

	Operating Leases		Finance Leases
	(In millions)
Right-of-use assets — net (a)	$	447	$	299
Lease obligations:
Current	$	182	$	17
Long-term		353		238
Total lease obligations	$	535	$	255

(a)	Finance lease ROU assets have a cost of $381 million and accumulated amortization of $82 million.

Schedule of Maturities of Lease Obligations

Maturities of lease obligations at December 31, 2019 were as follows:

	Operating Leases			Finance Leases
	(In millions)
2020	$	200		$	36
2021		72			36
2022		65			36
2023		64			36
2024		65			36
Remaining years		133			212
Total lease payments		599			392
Less: Imputed interest		(64	)		(137	)
Total lease obligations	$	535		$	255

Summary of Information Relates to Operating and Finance Leases Recorded

The following information relates to the Operating and Finance leases recorded at December 31, 2019:

	Operating Leases	Finance Leases
Weighted average remaining lease term	5.4 years	13.8 years
Range of remaining lease terms	0.1 - 16.1 years	13.8 years
Weighted average discount rate	4.3%	7.9%

Schedule of Components of Lease Cost

The components of lease costs for the year ended December 31, 2019 were as follows (in millions):

Operating lease cost	$	414
Finance lease cost:
Amortization of leased assets		43
Interest on lease obligations		21
Short-term lease cost (a)		164
Variable lease cost (b)		89
Sublease income (c)		(12	)
Total lease cost (d)	$	719

(a)	Short-term lease cost is primarily attributable to equipment used in global exploration, development, and production activities. Future short-term lease costs will vary based on activity levels of our operated assets.

(b)

(c)	We sublease certain of our office space to third parties under our head lease.

(d)	Prior to the adoption of ASC 842, we incurred total rental expense of $154 million in 2018 (2017: $123 million) and income from subleases of $8 million (2017: $10 million).

Supplemental Cash Flow Information Related to Leases

Supplemental cash flow information related to leases for the year ended December 31, 2019 was as follows:

	Operating Leases		Finance Leases
	(In millions)
Cash paid for amounts included in the measurement of lease obligations:
Operating cash flows (a)	$	419	$	21
Financing cash flows (a)		—		55
Noncash transactions:
Leased assets recognized for new lease obligations incurred	14			—

(a)	Amounts represent gross lease payments before any recovery from partners.

Income Taxes - Deferred Tax Assets and Liabilities, Net (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Deferred income taxes	$ 80	$ 21
Deferred income taxes (long-term liability)	(415)	(421)
Net Deferred Tax Assets (Liabilities)	$ (335)	$ (400)

Income Taxes - Effective Income Tax Rate Reconciliation (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Federal corporate tax rate	21.00%	21.00%	35.00%
Decrease in net deferred tax asset due to tax reform			$ 1,336

Income Taxes - Income (Loss) Before Income Taxes (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income (Loss) Before Income Taxes - United States	$ (338)	$ (219)	$ (2,784)
Income (Loss) Before Income Taxes - Foreign	559	439	(2,994)
Income (Loss) Before Income Taxes	$ 221	$ 220	$ (5,778)

Supplementary Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2019

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:

	2019			2018			2017
	(In millions)
Cash Flows From Operating Activities
Interest paid	$	(380	)	$	(394	)	$	(314	)
Net income taxes (paid) refunded		(417	)		(463	)		(210	)

Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P:
Capital expenditures incurred - E&P	$	(2,576	)	$	(1,909	)	$	(1,852	)
Increase (decrease) in related liabilities		143			55			64
Additions to property, plant and equipment - E&P	$	(2,433	)	$	(1,854	)	$	(1,788	)

Additions to property, plant and equipment - Midstream:
Capital expenditures incurred - Midstream	$	(416	)	$	(271	)	$	(121	)
Increase (decrease) in related liabilities		20			28			(28	)
Additions to property, plant and equipment - Midstream	$	(396	)	$	(243	)	$	(149	)

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
Document and Entity Information - USD ($) $ in Millions	Dec. 31, 2019	Jan. 31, 2020	Jun. 28, 2019
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Trading Symbol	HES
Entity Registrant Name	Hess Corporation
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock
Entity Interactive Data Current	Yes
Entity File Number	1-1204
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	13-4921002
Entity Address, Address Line One	1185 AVENUE OF THE AMERICAS
Entity Address, City or Town	NEW YORK
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10036
City Area Code	212
Local Phone Number	997-8500
Document Annual Report	true
Document Transition Report	false
Entity Central Index Key	0000004447
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		305,214,587
Entity Public Float			$ 16,996
Documents Incorporated by Reference	Part III is incorporated by reference from the Proxy Statement for the 2020 annual meeting of stockholders.

Disposition (Tables)

12 Months Ended

Dec. 31, 2019

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:

	2019		2018		2017
	(In millions)
Equatorial Guinea (a)	$	—	$	—	$	69
Norway (b)		—		—		(55	)
Income (Loss) from Continuing Operations Before Income Taxes	$	—	$	—	$	14

(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.

Impairment

12 Months Ended

Dec. 31, 2019

Asset Impairment Charges [Abstract]

Impairment

13. Impairment

In the third quarter of 2017, 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 of 2017, 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. These 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. Each of the valuation methods used in the determination of the impairment charges above represent Level 3 fair value measurements.

Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 126	$ 484
Assets – Master netting arrangements	0	0
Assets - Net Fair Value of Derivative Contracts	126	484
Liabilities - Gross fair value of derivative contracts	(1)	(2)
Liabilities - Master netting arrangements	0	0
Liabilities - Net Fair Value of Derivative Contracts	(1)	(2)
Derivative Contracts Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	126	484
Liabilities - Gross fair value of derivative contracts	0	(2)
Derivative Contracts Designated as Hedging Instruments \| Commodity \| Other Current Assets
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	125	484
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments \| Interest Rate \| Other Assets (Noncurrent)
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	1
Liabilities - Gross fair value of derivative contracts	0
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	0
Liabilities - Gross fair value of derivative contracts	(1)
Derivative Contracts Not Designated as Hedging Instruments \| Foreign Exchange
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	0
Liabilities - Gross fair value of derivative contracts	$ (1)

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, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Lump-sum settlement payment included in Benefit payments	$ 27	$ 32
Funded Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	2,580	2,424
Unfunded Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Actuarial gains/losses resulted from a change	(22)	29
Accumulated benefit obligation	194	171
Changes in Discount Rate
Defined Benefit Plan Disclosure [Line Items]
Actuarial gains/losses resulted from a change	$ 465	$ 235

Income Taxes - Effective Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
U.S. statutory rate	21.00%	21.00%	35.00%
Effect of foreign operations	142.90%	141.20%	17.40%
State income taxes, net of Federal income tax	5.80%	(18.90%)	0.00%
Change in enacted tax laws	0.00%	0.00%	(23.60%)
Valuation allowance adjustment with tax law change	0.00%	0.00%	23.60%
Rate differential on U.S. loss	0.00%	0.00%	(4.10%)
Gains on asset sales, net	0.00%	0.00%	(2.20%)
Valuation allowance on current year operations	41.80%	55.20%	(14.90%)
Valuation allowance against previously benefited deferred tax assets	0.00%	0.00%	0.10%
Release valuation allowance against previously unbenefited deferred tax assets	(24.50%)	0.00%	0.00%
Noncontrolling interests in Midstream	(16.00%)	(15.90%)	0.80%
Intraperiod allocation	33.70%	(37.30%)	0.00%
Equity and executive compensation	2.20%	7.40%	(0.30%)
Other	1.20%	(0.30%)	0.00%
Total	208.10%	152.40%	31.80%

Segment Information - Financial Data by Operating Segment (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	$ (408)	$ (282)	$ (4,074)
Midstream Segment \| Operating Segments
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	144	120	42
Midstream Segment \| Operating Segments \| Pro Forma
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation		158	73
Exploration and Production \| Operating Segments
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	$ 53	51	(3,653)
Exploration and Production \| Operating Segments \| Pro Forma
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation		$ 13	$ 3,684

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References + Details

Consolidated Balance Sheet (Parenthetical) - $ / shares	12 Months Ended
Consolidated Balance Sheet (Parenthetical) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1.00	$ 1.00
Preferred stock, shares authorized	20,000,000	20,000,000
Preferred stock, shares issued	0	574,997
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	$ 1.00	$ 1.00
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	304,955,472	291,434,534

Financial Risk Management Activities - Additional Information (Detail) - 2020 - Designated as Cash Flow Hedges	12 Months Ended
	Dec. 31, 2019 bbl / d $ / bbl
West Texas Intermediate
Derivative Instruments Gain Loss [Line Items]
Average monthly floor price \| $ / bbl	55
Notional amount of outstanding average barrels of oil per day \| bbl / d	130,000
Brent
Derivative Instruments Gain Loss [Line Items]
Average monthly floor price \| $ / bbl	60
Notional amount of outstanding average barrels of oil per day \| bbl / d	20,000

Statement of Consolidated Equity - USD ($) $ in Millions	Total	Mandatory Convertible Preferred Stock	Common Stock	Capital in Excess of Par	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Total Hess Stockholders' Equity	Noncontrolling Interests
Balance at Dec. 31, 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	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	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
Net income (loss)	(240)	0	0	0	(408)	0	(408)	168
Other comprehensive income (loss)	(393)	0	0	0	0	(393)	(393)	0
Preferred stock conversion	0	(1)	12	(11)	0	0	0	0
Share-based compensation	125	0	2	123	0	0	125	0
Dividends on preferred stock	(4)	0	0	0	(4)	0	(4)	0
Dividends on common stock	(310)	0	0	0	(310)	0	(310)	0
Conversion of Midstream structure	(7)	0	0	15	0	0	15	(22)
Sale of water business to Hess Infrastructure Partners	0	0	0	78	0	0	78	(78)
Noncontrolling interests, net	(353)	0	0	0	0	0	0	(353)
Balance at Dec. 31, 2019	$ 9,706	$ 0	$ 305	$ 5,591	$ 3,535	$ (699)	$ 8,732	$ 974

Share-based Compensation (Tables)

12 Months Ended

Dec. 31, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Share-based Compensation Activity

Share‑based compensation expense consisted of the following:

	2019		2018		2017
	(In millions)
Restricted stock	$	53	$	40	$	56
Stock options		10		10		9
Performance share units		22		22		21
Share-based compensation expense before income taxes	$	85	$	72	$	86
Income tax benefit on share-based compensation expense	$	—	$	—	$	1

Summary of Restricted Stock Award Activity

The following is a summary of restricted stock award activity in 2019:

		Shares of Restricted Common Stock			Weighted - Average Price on Date of Grant
	(In thousands, except per share amounts)
Outstanding at January 1, 2019			2,881		$	48.70
Granted			965			56.87
Vested (a)			(1,742	)		47.35
Forfeited			(90	)		52.67
Outstanding at December 31, 2019			2,014		$	53.61

(a)

In 2019, restricted stock with fair values of $102 million were vested (2018: $54 million; 2017: $37 million).

Summary of PSU Activity

The following is a summary of PSU activity in 2019:

	Performance Share Units			Weighted - Average Fair Value on Date of Grant
	(In thousands, except per share amounts)
Outstanding at January 1, 2019		1,063		$	53.98
Granted		269			68.87
Vested (a)		(391	)		51.00
Forfeited		(12	)		52.05
Outstanding at December 31, 2019		929		$	59.57

(a)

In 2019, PSU’s with fair value of $16 million were vested (2018: $9 million; 2017: $10 million).

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:

	2019			2018			2017
Risk free interest rate		2.48	%		2.39	%		1.55	%
Stock price volatility		0.369			0.400			0.387
Contractual term in years		3.0			3.0			3.0
Grant date price of Hess common stock	$	56.74		$	48.48		$	51.03

Summary of Stock Option Activity

The following is a summary of stock options activity in 2019:

	Number of options (In thousands)			Weighted Average Exercise Price per Share		Weighted Average Remaining Contractual Term
Outstanding at January 1, 2019		5,170		$	61.91	4.3 years
Granted		527			56.74
Exercised		(744	)		54.23
Forfeited		(652	)		57.69
Outstanding at December 31, 2019		4,301		$	63.24	4.8 years

Weighted Average Assumptions Utilized to Estimate Fair Value of Stock Options

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

	2019			2018			2017
Risk free interest rate		2.55	%		2.74	%		2.17	%
Stock price volatility		0.359			0.322		0.333
Dividend yield		1.76	%		2.06	%		1.96	%
Expected life in years		6.0			6.0			6.0
Weighted average fair value per option granted	$	18.08		$	13.69		$	14.51

Segment Information

12 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Segment Information

18. Segment Information

We currently have two operating segments, E&P and Midstream. The E&P operating segment explores for, develops, produces, purchases and sells crude oil, NGL and natural gas. Production operations over the three years ended December 31, 2019 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 NGL, transportation of crude oil by rail car, terminaling and loading crude oil and NGL, 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
2019
Sales and Other Operating Revenues - Third parties	$	6,495		$	—	$	—		$	—		$	6,495
Intersegment Revenues		—			848		—			(848	)		—
Sales and Other Operating Revenues	$	6,495		$	848	$	—		$	(848	)	$	6,495

Net Income (Loss) Attributable to Hess Corporation	$	53		$	144	$	(605	)	$	—		$	(408	)
Interest Expense		—			63		317			—			380
Depreciation, Depletion and Amortization		1,977			142		3			—			2,122
Provision (Benefit) for Income Taxes (a)		375			—		86			—			461
Investment in Affiliates		114			108		—			—			222
Identifiable Assets		16,790			3,499		1,493			—			21,782
Capital Expenditures		2,576			416		—			—			2,992

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	)
Capital Expenditures		1,852			121		—			—			1,973

(a)

Commencing January 1, 2019, management changed its measurement of segment earnings to reflect income taxes on a post U.S. tax consolidation and valuation allowance assessment basis. In 2018 and 2017, the provision for income taxes in the Midstream segment was presented before consolidating its operations with other U.S. activities of the Corporation and prior to evaluating realizability of net U.S. deferred taxes. An offsetting impact was presented in the E&P segment. If 2018 and 2017 segment results were prepared on a basis consistent with 2019, Midstream segment net income attributable to Hess Corporation would have been $158 million and $73 million, respectively, and E&P net income (loss) attributable to Hess Corporation would have been income of $13 million and a loss of $3,684 million, respectively.

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)
2019
Sales and Other Operating Revenues	$	5,043		$	139		$	551	$	762		$	—		$	6,495
Net Income (Loss) Attributable to Hess Corporation		15			2			36		144			(605	)		(408	)
Depreciation, Depletion and Amortization		1,631			53			21		414			3			2,122
Provision (Benefit) for Income Taxes		—			1			425		(51	)		86			461
Identifiable Assets		14,234			1,070			399		4,586			1,493			21,782
Property, Plant and Equipment (Net)		12,182			871			350		3,399			12			16,814
Capital Expenditures		2,094			40			15		843			—			2,992

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	)
Capital Expenditures		1,387			141			30		415			—			1,973

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2019

Property Plant And Equipment [Abstract]

Components of Property, Plant and Equipment

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

	2019		2018
	(In millions)
Exploration and Production
Unproved properties	$	168	$	394
Proved properties		3,304		3,124
Wells, equipment and related facilities		28,404		26,173
		31,876		29,691
Midstream		3,904		3,492
Corporate and Other		40		39
Total — at cost		35,820		33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment		19,006		17,139
Property, Plant and Equipment — Net	$	16,814	$	16,083

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:

	2019			2018			2017
	(In millions)
Balance at January 1	$	418		$	304		$	597
Additions to capitalized exploratory well costs pending the determination of proved reserves		224			128			116
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(58	)		—			(165	)
Capitalized exploratory well costs charged to expense		—			(14	)		(268	)
Dispositions and other		—			—			24
Balance at December 31	$	584		$	418		$	304
Number of Wells at December 31		31			24			12

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 $400 million at December 31, 2019, separated by year of completion as follows (in millions):

2018	$	157
2017		73
2016		—
2015		166
2014 and prior		4
	$	400

Retirement Plans

12 Months Ended

Dec. 31, 2019

Compensation And Retirement Disclosure [Abstract]

Retirement Plans

10. 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
	2019			2018			2019			2018			2019			2018
	(In millions)
Change in Benefit Obligation
Balance at January 1,	$	2,492		$	2,765		$	216		$	249		$	59		$	87
Service cost		33			30			11			12			2			2
Interest cost		82			84			7			7			2			3
Actuarial (gains) loss (a)		401			(237	)		22			(29	)		19			(24	)
Single premium annuity contract payment		(249	)		—			—			—			—			—
Benefit payments (b)		(113	)		(110	)		(14	)		(19	)		(7	)		(7	)
Plan curtailments		—			(10	)		—			(4	)		—			(2	)
Plan amendments		—			4			—			—			—			—
Foreign currency exchange rate changes		21			(34	)		—			—			—			—
Balance at December 31, (c)		2,667			2,492			242			216			75			59
Change in Fair Value of Plan Assets
Balance at January 1,	$	2,568		$	2,732		$	—		$	—		$	—		$	—
Actual return on plan assets		462			(77	)		—			—			—			—
Employer contributions		40			59			14			19			7			7
Single premium annuity contract payment		(249	)		—			—			—			—			—
Benefit payments (b)		(113	)		(110	)		(14	)		(19	)		(7	)		(7	)
Foreign currency exchange rate changes		24			(36	)		—			—			—			—
Balance at December 31,		2,732			2,568			—			—			—			—

Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	$	65		$	76		$	(242	)	$	(216	)	$	(75	)	$	(59	)

Unrecognized Net Actuarial (Gains) Losses	$	756		$	778		$	65		$	47		$	(12	)	$	(32	)

(a)	Changes in discount rates resulted in actuarial losses of approximately $465 million in 2019 (2018: $235 million of actuarial gains from changes in discount rates).

(b)	Benefit payments include lump-sum settlement payments of approximately $27 million in 2019 (2018: $32 million).

(c)	At December 31, 2019, the accumulated benefit obligation for the funded and unfunded defined benefit pension plans was $2,580 million and $194 million, respectively (2018: $2,424 million and $171 million, respectively).

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

	Funded					Unfunded						Postretirement
	Pension Plans					Pension Plan						Medical Plan
	2019			2018		2019			2018			2019			2018
	(In millions)
Noncurrent assets	$	71		$	76	$	—		$	—		$	—		$	—
Current liabilities		—			—		(32	)		(30	)		(8	)		(9	)
Noncurrent liabilities		(6	)		—		(210	)		(186	)		(67	)		(50	)
Pension assets / (accrued benefit liability)	$	65		$	76	$	(242	)	$	(216	)	$	(75	)	$	(59	)

Accumulated other comprehensive loss, pre-tax (a)	$	756		$	778	$	65		$	47		$	(12	)	$	(32	)

(a)	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $601 million at December 31, 2019 (2018: $581 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
	2019			2018			2017			2019			2018			2017
	(In millions)
Service cost	$	44		$	42		$	49		$	2		$	2		$	4
Interest cost		89			91			102			2			3			3
Expected return on plan assets		(180	)		(194	)		(168	)		—			—			—
Amortization of unrecognized net actuarial losses (gains)		52			39			58			(1	)		(2	)		—
Settlement loss		93			4			19			—			—			—
Curtailment gain		—			—			—			—			(2	)		—
Net Periodic Benefit Cost (a)	$	98		$	(18	)	$	60		$	3		$	1		$	7

(a)	Net non-service pension costs are included in Other, net in the Statement of Consolidated Income. In 2019, net non-service pension costs amounted to an expense of $55 million (2018: $61 million of income; 2017: $14 million of expense).

In 2019, the trust for the Hess Corporation Employees’ Pension Plan (the “Plan”) purchased a single premium annuity contract at a cost of approximately $250 million using assets of the Plan to settle and transfer certain of its obligations to a third party. The settlement transaction resulted in a noncash charge of $88 million to recognize unamortized pension actuarial losses that is included in Other, net in the Statement of Consolidated Income. In connection with this settlement transaction, as required under U.S. accounting standards, we remeasured the Plan, which resulted in a net increase in Plan liabilities of $239 million driven by a change in the weighted average discount rate used and an update to the fair value of Plan assets.

In 2020, we forecast pension service costs for our pension and postretirement medical plans to be approximately $55 million and net non-service pension costs of approximately $55 million of income, which is comprised of interest cost of approximately $75 million, amortization of unrecognized net actuarial losses of approximately $50 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:

	2019			2018			2017
Benefit Obligations:
Discount rate		2.9	%		3.9	%		3.3	%
Rate of compensation increase		3.8	%		3.8	%		4.5	%

Net Periodic Benefit Cost:
Discount rate
Service cost		3.9	%		3.9	%		3.7	%
Interest cost		3.4	%		3.3	%		3.7	%
Expected return on plan assets		7.1	%		7.2	%		7.3	%
Rate of compensation increase		3.8	%		4.5	%		4.6	%

The actuarial assumptions used to determine Benefit obligations at December 31 for the postretirement medical plan were as follows:

	2019			2018			2017

Discount rate		2.8	%		3.9	%		3.2	%
Initial health care trend rate		6.5	%		6.9	%		7.3	%
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 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 45% equity securities, 35% 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, 2019 and 2018 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, 2019
Cash and Short-Term Investment Funds	$	57	$	—	$	—	$	—	$	57
Equities:
U.S. equities (domestic)		638		—		—		—		638
International equities (non-U.S.)		80		37		—		302		419
Global equities (domestic and non-U.S.)		—		8		—		196		204
Fixed Income:
Treasury and government issued (a)		—		210		—		—		210
Government related (b)		—		162		—		56		218
Mortgage-backed securities (c)		—		141		—		30		171
Corporate		—		293		—		82		375
Other:
Hedge funds		—		—		—		65		65
Private equity funds		—		—		—		191		191
Real estate funds		27		—		—		157		184
Total investments	$	802	$	851	$	—	$	1,079	$	2,732

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		—		—		111		160
Diversified commodities funds		—		19		—		—		19
Total investments	$	800	$	1,006	$	—	$	762	$	2,568

(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 (NAV) 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. In 2019, we elected to apply the NAV practical expedient to the plan’s investments in non-exchange traded Real Estate Funds and, as such, have presented investments in Real Estate Funds that were previously categorized as Level 3 at December 31, 2018 totaling $61 million on a basis consistent with 2019.

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 which are classified as Level 1.

Equities - Consists of individually held U.S. and International equity securities. This investment category also includes funds that consist primarily U.S. and international equity securities. Equity securities, which are individually held and are traded actively on exchanges, are classified as Level 1. Certain funds, consisting primarily of equity securities, are classified as Level 2 if the NAV is determined and published daily, and is the basis for current transactions. Commingled funds, consisting primarily of equity securities, are valued using the NAV per fund share.

Fixed income investments - Consists of individually held 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 funds that consist of 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 assets of the particular plan and are classified as Level 2. Certain funds, consisting primarily of fixed income securities, are classified as Level 2 if the NAV is determined and published daily, and is the basis for current transactions. Commingled funds, consisting primarily of fixed income securities, are valued using the NAV per fund share.

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.

Contributions and estimated future benefit payments: We expect to contribute approximately $45 million to our funded pension plans in 2020.

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):

2020	$	127
2021		126
2022		128
2023		130
2024		133
Years 2025 to 2029		674

We also have 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 $20 million in 2019 for contributions to these plans (2018: $19 million; 2017: $22 million).

Financial Risk Management Activities

12 Months Ended

Dec. 31, 2019

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Financial Risk Management Activities

19. 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, 2019, these forward contracts relate to the British Pound and the Danish Krone. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.

The notional amounts of outstanding financial risk management derivative contracts were as follows:

	December 31, 2019		December 31, 2018
	(In millions)
Commodity - crude oil (millions of barrels)		54.9		34.7
Foreign exchange	$	90	$	16
Interest rate swaps	$	100	$	100

For calendar year 2020 we have West Texas Intermediate (WTI) put options with an average monthly floor price of $55 per barrel for 130,000 bopd, and Brent put options with an average monthly floor price of $60 per barrel for 20,000 bopd.

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, 2019
Derivative Contracts Designated as Hedging Instruments:
Commodity - Other current assets	$	125	$	—
Interest rate - Other assets (noncurrent)		1		—
Total derivative contracts designated as hedging instruments		126		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange		—		(1	)
Total derivative contracts not designated as hedging instruments		—		(1	)
Gross fair value of derivative contracts		126		(1	)
Master netting arrangements		—		—
Net Fair Value of Derivative Contracts	$	126	$	(1	)

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	)

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 2019, crude oil price hedging contracts increased Sales and other operating revenues by $1 million (2018: decrease of $161 million; 2017: decrease of $34 million). At December 31, 2019, pre-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding crude oil price hedging contracts were $98 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, 2019, we had interest rate swaps with gross notional amounts of $100 million (2018: $100 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. 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 2019, the change in fair value of interest rate swaps was a decrease in the derivative liability of $3 million (2018: $1 million increase in liability; 2017: $4 million increase in liability) with a corresponding adjustment in the carrying value of the hedged fixed‑rate debt. During 2018, we terminated interest rate swaps with a gross notional amount of $350 million and paid $3 million.

Impact on statement of consolidated income from derivative contracts not designated as hedging instruments:

Crude oil collars: In 2018, noncash adjustments to de-designated crude 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 gain of $3 million in 2019 (2018: loss of $5 million; 2017: gain of $15 million) and are reported in Other, net in Revenues and non-operating income in the Statement of Consolidated Income. A component of foreign exchange gains or losses is the result of foreign exchange derivative contracts that are not designated as hedges, which amounted to a loss of $2 million in 2019 (2018: loss of $2 million; 2017: gain of $3 million).

In 2017, after‑tax foreign currency translation adjustments included in the Statement of Consolidated Comprehensive Income amounted to gains of $144 million. In addition, $900 million of cumulative currency translation losses were recognized in earnings as a result of the sale of our assets in Norway. See 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, 2019, our Accounts receivable were concentrated with the following counterparty industry segments: Integrated companies — 41%, Independent E&P companies — 26%, Refining and marketing companies — 14%, National oil companies — 8%, Storage and transportation companies — 5%, and Others — 6%. 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, 2019, we had outstanding letters of credit totaling $272 million (2018: $284 million).

Fair Value Measurement: At December 31, 2019, our total long-term debt, which was substantially comprised of fixed rate debt instruments, had a carrying value of $7,142 million and a fair value of $8,242 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, 2019 and December 31, 2018.

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

9. Asset Retirement Obligations

The following table describes changes to our asset retirement obligations:

	2019			2018
	(In millions)
Balance at January 1	$	857		$	801
Liabilities incurred		72			68
Liabilities settled or disposed of		(75	)		(46	)
Accretion expense		40			37
Revisions of estimated liabilities		129			1
Foreign currency remeasurement		1			(4	)
Balance at December 31	$	1,024		$	857

Total Asset Retirement Obligations at December 31:
Current portion of asset retirement obligations	$	127		$	116
Long-term asset retirement obligations		897			741
Total at December 31	$	1,024		$	857

The liabilities incurred in 2019 primarily relate to operations in Guyana, the U.S. and Malaysia, while liabilities incurred in 2018 primarily relate to operations in the U.S. and UK as well as acquired participating interests. The liabilities settled or disposed of primarily reflect activity in the Gulf of Mexico and the Bakken in 2019, while activity in 2018 primarily relates to abandonment activity and an asset disposal onshore in the U.S. The revisions of estimated liabilities in 2019 reflect an acceleration of planned abandonment activity in the Gulf of Mexico and changes in service and equipment rates.

The fair value of sinking fund deposits that are legally restricted for purposes of settling asset retirement obligations, which are reported in non-current Other assets in the Consolidated Balance Sheet, was $178 million at December 31, 2019 (2018: $148 million).

Outstanding and Weighted Average Common Shares

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Outstanding and Weighted Average Common Shares

15. Outstanding and Weighted Average Common Shares

The Net income (loss) and weighted average number of common shares used in basic and diluted earnings per share computation were as follows:

	2019			2018			2017
	(In millions except per share amounts)
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Net income (loss)	$	(240	)	$	(115	)	$	(3,941	)
Less: Net income (loss) attributable to noncontrolling interests		168			167			133
Less: Preferred stock dividends		4			46			46
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(412	)	$	(328	)	$	(4,120	)

Weighted Average Number of Common Shares Outstanding:
Basic		301.2			298.2			314.1
Effect of dilutive securities
Restricted common stock		—			—			—
Stock options		—			—			—
Performance share units		—			—			—
Mandatory convertible preferred stock		—			—			—
Diluted		301.2			298.2			314.1

Net Income (Loss) Attributable to Hess Corporation per Common Share:
Basic	$	(1.37	)	$	(1.10	)	$	(13.12	)
Diluted	$	(1.37	)	$	(1.10	)	$	(13.12	)

Antidilutive shares excluded from the computation of diluted shares:
Restricted common stock		2.2			2.9			3.3
Stock options		4.7			5.5			6.4
Performance share units		1.7			1.1			0.6
Common shares from conversion of preferred stock		—			12.7			12.8

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

	2019		2018			2017
	(In millions)
Balance at January 1		291.4		315.1			316.5
Conversion of preferred stock		11.6		—			—
Activity related to restricted stock awards, net		0.9		0.8			0.8
Stock options exercised		0.7		0.6			0.2
PSU vested		0.3		0.1			0.2
Shares repurchased		—		(25.2	)		(2.6	)
Balance at December 31		304.9		291.4			315.1

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 (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 Preferred Stock were payable on a cumulative basis. Unless converted earlier, each share of Preferred Stock would 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.

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 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 January 31, 2019, the 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 and 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.

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). At December 31, 2019, we are authorized, but not required, to purchase additional common stock up to a value of $650 million.

Common stock dividends:

In 2019, 2018 and 2017, cash dividends declared on common stock totaled $1.00 per share ($0.25 per quarter).

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenues and Non-Operating Income
Sales and other operating revenues	$ 6,495	$ 6,323	$ 5,466
Gains (losses) on asset sales, net	22	32	(86)
Other, net	(7)	111	11
Total revenues and non-operating income	6,510	6,466	5,391
Costs and Expenses
Marketing, including purchased oil and gas	1,736	1,771	1,267
Operating costs and expenses	1,237	1,134	1,443
Production and severance taxes	184	171	119
Exploration expenses, including dry holes and lease impairment	233	362	507
General and administrative expenses	397	473	422
Interest expense	380	399	325
Loss on debt extinguishment	0	53	0
Depreciation, depletion and amortization	2,122	1,883	2,883
Impairment	0	0	4,203
Total costs and expenses	6,289	6,246	11,169
Income (Loss) Before Income Taxes	221	220	(5,778)
Provision (benefit) for income taxes	461	335	(1,837)
Net Income (Loss)	(240)	(115)	(3,941)
Less: Net income (loss) attributable to noncontrolling interests	168	167	133
Net Income (Loss) Attributable to Hess Corporation	(408)	(282)	(4,074)
Less: Preferred stock dividends	4	46	46
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (412)	$ (328)	$ (4,120)
Net Income (Loss) Attributable to Hess Corporation Per Common Share
Basic	$ (1.37)	$ (1.10)	$ (13.12)
Diluted	$ (1.37)	$ (1.10)	$ (13.12)
Weighted Average Number of Common Shares Outstanding (Diluted)	301.2	298.2	314.1
Common Stock Dividends Per Share	$ 1.00	$ 1.00	$ 1.00

Leases - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease right-of-use assets — net	$ 447	$ 0
Operating Leases, Lease obligations:
Operating Leases, Lease Liabilities, Current	182
Long-term operating lease obligations	353	0
Operating Leases, Total lease obligations	535
Finance lease right-of-use assets — net	299	0
Financing Leases, Lease obligations:
Financing Leases, Lease liabilities, Current	17
Financing Leases, Lease liabilities, Long-term	238	$ 0
Financing Leases, Total lease obligations	$ 255

Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	$ 6,495	$ 6,323	$ 5,466
Intersegment revenues	0	0	0
Total sales and other operating revenues	6,495	6,323	5,466
Net Income (Loss) Attributable to Hess Corporation	(408)	(282)	(4,074)
Interest Expense	380	399	325
Depreciation, Depletion and Amortization	2,122	1,883	2,883
Impairment			4,203
Provision (Benefit) for Income Taxes	461	335	(1,837)
Investment in Affiliates	222	193
Identifiable Assets	21,782	21,433
Capital Expenditures	2,992	2,180	1,973
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0
Intersegment revenues	(848)	(713)	(611)
Total sales and other operating revenues	(848)	(713)	(611)
Net Income (Loss) Attributable to Hess Corporation	0	0	0
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	0	0	0
Impairment			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	6,495	6,323	5,460
Intersegment revenues	0	0	0
Total sales and other operating revenues	6,495	6,323	5,460
Net Income (Loss) Attributable to Hess Corporation	53	51	(3,653)
Interest Expense	0	0	0
Depreciation, Depletion and Amortization	1,977	1,748	2,736
Impairment			4,203
Provision (Benefit) for Income Taxes	375	391	(1,842)
Investment in Affiliates	114	126
Identifiable Assets	16,790	16,109
Capital Expenditures	2,576	1,909	1,852
Midstream \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	6
Intersegment revenues	848	713	611
Total sales and other operating revenues	848	713	617
Net Income (Loss) Attributable to Hess Corporation	144	120	42
Interest Expense	63	60	26
Depreciation, Depletion and Amortization	142	127	123
Impairment			0
Provision (Benefit) for Income Taxes	0	38	31
Investment in Affiliates	108	67
Identifiable Assets	3,499	3,285
Capital Expenditures	416	271	121
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	(605)	(453)	(463)
Interest Expense	317	339	299
Depreciation, Depletion and Amortization	3	8	24
Impairment			0
Provision (Benefit) for Income Taxes	86	(94)	(26)
Investment in Affiliates	0	0
Identifiable Assets	1,493	2,039
Capital Expenditures	$ 0	$ 0	$ 0

Retirement Plans - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
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.
Settlement loss			$ 93	$ 4	$ 19
Budgeted contributions to funded pension plans for next year			45
Expense for defined contribution plans			$ 20	19	22
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets			45.00%
Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets			35.00%
Other Types of Investments
Defined Benefit Plan Disclosure [Line Items]
Current target allocations for plan assets			20.00%
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Settlement loss	$ 88		$ 93	4	19
Single premium annuity contract cost	250		250
Net increase in post retirement plan liabilities	$ 239		239
Service costs			44	42	49
Interest costs			89	91	102
Amortization of unrecognized net actuarial losses			52	39	58
Expected return on plan assets			$ (180)	$ (194)	$ (168)
Scenario Forecast
Defined Benefit Plan Disclosure [Line Items]
Service costs		$ 55
Net non-service pension costs		55
Interest costs		75
Amortization of unrecognized net actuarial losses		50
Expected return on plan assets		$ (180)

Debt - Other Outstanding Letters of Credit (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 272	$ 284
Committed Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	54	29
Uncommitted Lines
Line Of Credit Facility [Line Items]
Other outstanding letters of credit	$ 218	$ 255

Exit and Disposal Costs

12 Months Ended

Dec. 31, 2019

Restructuring And Related Activities [Abstract]

Exit and Disposal Costs

12. Exit and Disposal Costs

In 2018, we incurred severance expense of $38 million (2017: $18 million) associated with asset sales and cost savings initiatives in response to low crude oil prices. In 2019, we paid accrued severance costs of $4 million (2018: $40 million; 2017: $48 million).

Leases - Additional Information (Detail)	12 Months Ended
Leases - Additional Information (Detail)	Dec. 31, 2019	Dec. 31, 2018
Leases [Line Items]
Lease obligations as percentage of present value of future minimum lease payments in lease arrangement	100.00%
Lease payments as a percentage of lease costs	100.00%
Floating, Storage and Offloading Vessel
Leases [Line Items]
North Malay Basin, offshore Peninsular Malaysia - Hess operated interest	50.00%	50.00%
Finance lease term	13 years 9 months 18 days

Nature of Operations, Basis of Presentation and Summary of Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Basis of Presentation and Principles of Consolidation

	December 31, 2018		Adjustment for Finance Leases			Adjustment for Operating Leases			January 1, 2019
	(In millions)
Assets
Property, plant and equipment — net	$	16,083	$	(346	)	$	—		$	15,737
Operating lease right-of-use assets — net		—		—			804			804
Finance lease right-of-use assets — net		—		346			—			346
Liabilities
Accrued liabilities		1,560		—			(2	)		1,558
Current maturities of long-term debt		67		(55	)		—			12
Current portion of operating and finance lease obligations		—		55			382			437
Long-term debt		6,605		(254	)		—			6,351
Long-term operating lease obligations		—		—			516			516
Long-term finance lease obligations		—		254			—			254
Other liabilities and deferred credits		575		—			(92	)		483

Estimates and Assumptions

Revenue Recognition

Revenue Recognition:

Exploration and Production

Contract types:

The following is a summary of contract types for our E&P segment:

Contract Balances:

Transaction Price Allocated to Remaining Performance Obligations:

Sales-based Taxes:

Midstream

Our Midstream segment provides gathering, compression, processing, fractionation, storage, terminaling, loading and transportation, and water handling services.

Exploration and Development Costs

Depreciation, Depletion and Amortization

Capitalized Interest

Impairment of Long-lived Assets

Impairment of Goodwill

Cash and Cash Equivalents

Inventories

Income Taxes

Asset Retirement Obligations

Retirement Plans

Derivatives

Fair Value Measurements

Details on the methods and assumptions used to determine the fair values are as follows:

Share-based Compensation

Foreign Currency Translation

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

New Accounting Pronouncements

Revenue

12 Months Ended

Dec. 31, 2019

Revenue From Contract With Customer [Abstract]

Revenue

2. Revenue

Revenue from contracts with customers on a disaggregated basis was as follows (in millions):

	Exploration and Production												Midstream		Eliminations			Total
	United States			Europe		Africa		Asia		E&P Total
2019
Sales of our net production volumes:
Crude oil revenue	$	2,981		$	130	$	436	$	113	$	3,660		$	—	$	—		$	3,660
Natural gas liquids revenue		229			—		—		—		229			—		—			229
Natural gas revenue		150			9		24		646		829			—		—			829
Sales of purchased oil and gas		1,644			—		91		3		1,738			—		—			1,738
Intercompany revenue		—			—		—		—		—			848		(848	)		—
Total revenues from contracts with customers		5,004			139		551		762		6,456			848		(848	)		6,456
Other operating revenues (a)		39			—		—		—		39			—		—			39
Total sales and other operating revenues	$	5,043		$	139	$	551	$	762	$	6,495		$	848	$	(848	)	$	6,495

	Exploration and Production												Midstream		Eliminations			Total
	United States			Europe		Africa		Asia		E&P Total
2018
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.

Outstanding and Weighted Average Common Shares - Changes in Outstanding Common Shares (Detail) - shares shares in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Stockholders Equity Note [Abstract]
Balance at January 1	291.4	315.1	316.5
Conversion of preferred stock	11.6	0.0	0.0
Activity related to restricted stock awards, net	0.9	0.8	0.8
Stock options exercised	0.7	0.6	0.2
PSU vested	0.3	0.1	0.2
Shares repurchased	0.0	(25.2)	(2.6)
Balance at December 31	304.9	291.4	315.1

Inventories

12 Months Ended

Dec. 31, 2019

Inventory Disclosure [Abstract]

Inventories

4. Inventories

Inventories at December 31 were as follows:

	2019		2018
	(In millions)
Crude oil and natural gas liquids	$	92	$	74
Materials and supplies		169		171
Total Inventories	$	261	$	245

Leases - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Parenthetical) (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Leases [Abstract]
Finance lease ROU cost	$ 381
Finance lease, right-of-use assets, accumulated amortization	$ 82

Share-based Compensation - Weighted Average Assumptions Utilized to Estimate Fair Value of PSU Awards (Detail) - Performance Share Units - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk free interest rate	2.48%	2.39%	1.55%
Stock price volatility	0.369%	0.40%	0.387%
Contractual term in years	3 years	3 years	3 years
Grant date price of Hess common stock	$ 56.74	$ 48.48	$ 51.03

Nature of Operations, Basis of Presentation and Summary of Accounting Policies - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019	Dec. 31, 2016
Basis of Presentation and Principles of Consolidation [Abstract]
Cumulative effect of retained earnings			$ 0		$ (37,000,000)
Contract asset	$ 0	$ 0
Contract liability	0	0
Goodwill	360,000,000	360,000,000
Environmental Property Sale, Disposal or Abandonment Costs [Abstract]
Reserve for estimated remediation liabilities	70,000,000
Exploration and Production
Basis of Presentation and Principles of Consolidation [Abstract]
Credit losses on receivables with customers	$ 0	$ 0
Midstream
Basis of Presentation and Principles of Consolidation [Abstract]
Initial revenue contract period	10 years	10 years	10 years
Additional revenue contract period	10 years	10 years	10 years
Goodwill	$ 360,000,000
ASC 842
Basis of Presentation and Principles of Consolidation [Abstract]
Cumulative effect of retained earnings				$ 0
Hess Midstream LP
Summary Of Significant Accounting Policies [Line Items]
Ownership percentage in variable interest entity	47.00%

Nature of Operations, Basis of Presentation and Summary of Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Schedule of Impact of adoption on Consolidated Balance Sheet

	December 31, 2018		Adjustment for Finance Leases			Adjustment for Operating Leases			January 1, 2019
	(In millions)
Assets
Property, plant and equipment — net	$	16,083	$	(346	)	$	—		$	15,737
Operating lease right-of-use assets — net		—		—			804			804
Finance lease right-of-use assets — net		—		346			—			346
Liabilities
Accrued liabilities		1,560		—			(2	)		1,558
Current maturities of long-term debt		67		(55	)		—			12
Current portion of operating and finance lease obligations		—		55			382			437
Long-term debt		6,605		(254	)		—			6,351
Long-term operating lease obligations		—		—			516			516
Long-term finance lease obligations		—		254			—			254
Other liabilities and deferred credits		575		—			(92	)		483

Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Balance at January 1	$ 168	$ 205	$ 424
Additions based on tax positions taken in the current year	2	19	14
Additions based on tax positions of prior years	1	36	4
Reductions based on tax positions of prior years	(1)	(78)	(147)
Reductions due to settlements with taxing authorities	0	(10)	(85)
Reductions due to lapses in statutes of limitation	(2)	(4)	(5)
Balance at December 31	$ 168	$ 168	$ 205

Hess Midstream - Additional Information (Detail) $ in Millions								12 Months Ended
	Dec. 16, 2019 USD ($) shares	Dec. 15, 2019	Mar. 22, 2019 USD ($)	Mar. 01, 2019 USD ($)	Jan. 25, 2018 MMcf	Apr. 10, 2017 USD ($) shares	Jul. 01, 2015 USD ($)	Dec. 31, 2019 USD ($) shares MMcf	Dec. 31, 2018 USD ($) shares	May 21, 2015
Variable Interest Entity [Line Items]
Cash and cash equivalents								$ 1,545.0	$ 2,694.0
Property, plant and equipment, net								$ 16,814.0	16,083.0
Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Cash and cash equivalents									109.0
Property, plant and equipment, net									2,664.0
Hess Midstream liabilities on a nonrecourse basis to Hess Corporation									$ 1,105.0
Hess Infrastructure Partners LP (HIP) \| Global Infrastructure Partners (GIP)
Variable Interest Entity [Line Items]
Noncontrolling interest ownership percentage		50.00%							50.00%
Hess Infrastructure Partners LP's IPO of Hess Midstream Partners LP
Variable Interest Entity [Line Items]
Initial public offering common units sold \| shares						16,997,000			16,997,000
Net proceeds from initial public offering						$ 365.5			$ 365.5
Percentage of limited partnership interest in Hess Midstream Partners						30.50%			30.50%
Percentage of general partnership interest						2.00%
Hess North Dakota Pipeline Operations LP \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Controlling economic interest, percentage						20.00%
Hess TGP Operations LP \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Controlling economic interest, percentage						20.00%
Hess North Dakota Export Logistics Operations LP \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Controlling economic interest, percentage						20.00%
Hess Mentor Storage Holdings LLC \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Controlling economic interest, percentage						100.00%
Hess Midstream Partners LP (Hess Midstream Partners) \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Acquired ownership interest percentage								80.00%
Hess Midstream Partners LP (Hess Midstream Partners) \| Little Missouri 4
Variable Interest Entity [Line Items]
Gas plant processing capacity \| MMcf					200			200
Joint venture percentage owned by Targa Resources Corp					50.00%			50.00%
Hess Midstream Partners LP (Hess Midstream Partners) \| Global Infrastructure Partners (GIP)
Variable Interest Entity [Line Items]
Percentage of limited partnership interest in Hess Midstream Partners						33.75%
Indirect ownership interest through Hess Infrastructure Partners LP (HIP), percentage						50.00%
HIP Acquisition of Hess' Existing Water Services Business
Variable Interest Entity [Line Items]
Acquisition of water business - cash paid				$ 225.0
Sale of water management business, after-tax gain offset to noncontrolling interests				$ 78.0
HIP and Hess Midstream Partners Acquisition of Water Gathering Assets of Summit Midstream Partners LP’s Tioga Gathering System
Variable Interest Entity [Line Items]
Cash consideration			$ 90.0
Contingent payments subject to certain future performance			$ 10.0
Creation of Hess Midstream LP
Variable Interest Entity [Line Items]
Cash received	$ 301.0							$ 301.0
Class B units issued to Hess Corporation \| shares	115,000,000							115,000,000
Common stock exchange ratio	100.00%							100.00%
Creation of Hess Midstream LP \| Global Infrastructure Partners (GIP)
Variable Interest Entity [Line Items]
Ownership percentage in variable interest entity	47.00%							47.00%
Hess Midstream LP
Variable Interest Entity [Line Items]
Ownership percentage in variable interest entity								47.00%
Cash and cash equivalents								$ 3.0
Property, plant and equipment, net								3,010.0
Hess Midstream liabilities on a nonrecourse basis to Hess Corporation								$ 1,941.0
Hess Corporation \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Ownership percentage in variable interest entity		50.00%							50.00%
Percentage of interest sold										50.00%
Proceeds from sale of interest							$ 2,600.0
Hess Corporation \| Hess Midstream Partners LP (Hess Midstream Partners)
Variable Interest Entity [Line Items]
Percentage of limited partnership interest in Hess Midstream Partners						33.75%
Indirect ownership interest through Hess Infrastructure Partners LP (HIP), percentage						50.00%
Hess Corporation \| Creation of Hess Midstream LP \| Class A Shares
Variable Interest Entity [Line Items]
Percentage of Class A Shares owned by public shareholders	6.00%							6.00%
Hess Corporation \| Hess Midstream LP
Variable Interest Entity [Line Items]
Ownership percentage in variable interest entity	47.00%

Subsequent Event

12 Months Ended

Dec. 31, 2019

Subsequent Events [Abstract]

Subsequent Event

20. Subsequent Event

In January 2020, the operator, Kosmos Energy Ltd, completed drilling of the Oldfield-1 exploration well in the Gulf of Mexico. The well did not encounter commercial quantities of hydrocarbons and 2019 results include $15 million in exploration expense for well costs incurred through December 31, 2019. We estimate approximately $15 million of exploration expense will be recognized in the first quarter of 2020 for well costs incurred after December 31, 2019.

Impairment - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Impairments [Line Items]
Impairment charge, pre-tax			$ 0	$ 0	$ 4,203
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 income taxes		$ 550
Stampede Field
Impairments [Line Items]
Impairment charge, pre-tax	1,095
Percentage of working interest prior to unitizing					100.00%
Impairment charge, after income taxes	1,095
Tubular Bells Field
Impairments [Line Items]
Impairment charge, pre-tax	605
Impairment charge, after income taxes	$ 605

Statement of Consolidated Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows From Operating Activities
Net income (loss)	$ (240)	$ (115)	$ (3,941)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Gains) losses on asset sales, net	(22)	(32)	86
Depreciation, depletion and amortization	2,122	1,883	2,883
Impairment	0	0	4,203
Exploratory dry hole costs	49	165	268
Exploration lease and other impairment	17	37	44
Pension settlement loss	93	4	19
Stock compensation expense	85	72	86
Noncash (gains) losses on commodity derivatives, net	116	182	97
Provision (benefit) for deferred income taxes and other tax accruals	17	(120)	(2,001)
Loss on debt extinguishment	0	53	0
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(383)	(138)	(340)
(Increase) decrease in inventories	(16)	(12)	(64)
Increase (decrease) in accounts payable and accrued liabilities	4	88	(44)
Increase (decrease) in taxes payable	16	(2)	(34)
Changes in other operating assets and liabilities	(216)	(126)	(317)
Net cash provided by (used in) operating activities	1,642	1,939	945
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(2,433)	(1,854)	(1,788)
Additions to property, plant and equipment - Midstream	(396)	(243)	(149)
Payments for Midstream equity investments	(33)	(67)	0
Proceeds from asset sales, net of cash sold	22	607	3,296
Other, net	(3)	(9)	(1)
Net cash provided by (used in) investing activities	(2,843)	(1,566)	1,358
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	32	0	(153)
Debt with maturities of greater than 90 days – Borrowings	760	0	800
Debt with maturities of greater than 90 days – Repayments	(8)	(633)	(459)
Payments on finance lease obligations	(49)	0	0
Proceeds from issuance of Hess Midstream Partnership LP units	0	0	366
Common stock acquired and retired	(25)	(1,365)	(110)
Cash dividends paid	(316)	(345)	(363)
Noncontrolling interests, net	(353)	(211)	(243)
Other, net	11	28	(26)
Net cash provided by (used in) financing activities	52	(2,526)	(188)
Net Increase (Decrease) in Cash and Cash Equivalents	(1,149)	(2,153)	2,115
Cash and Cash Equivalents at Beginning of Year	2,694	4,847	2,732
Cash and Cash Equivalents at End of Year	$ 1,545	$ 2,694	$ 4,847

Outstanding and Weighted Average Common Shares (Tables)

12 Months Ended

Dec. 31, 2019

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:

	2019			2018			2017
	(In millions except per share amounts)
Net Income (Loss) Attributable to Hess Corporation Common Stockholders:
Net income (loss)	$	(240	)	$	(115	)	$	(3,941	)
Less: Net income (loss) attributable to noncontrolling interests		168			167			133
Less: Preferred stock dividends		4			46			46
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(412	)	$	(328	)	$	(4,120	)

Weighted Average Number of Common Shares Outstanding:
Basic		301.2			298.2			314.1
Effect of dilutive securities
Restricted common stock		—			—			—
Stock options		—			—			—
Performance share units		—			—			—
Mandatory convertible preferred stock		—			—			—
Diluted		301.2			298.2			314.1

Net Income (Loss) Attributable to Hess Corporation per Common Share:
Basic	$	(1.37	)	$	(1.10	)	$	(13.12	)
Diluted	$	(1.37	)	$	(1.10	)	$	(13.12	)

Antidilutive shares excluded from the computation of diluted shares:
Restricted common stock		2.2			2.9			3.3
Stock options		4.7			5.5			6.4
Performance share units		1.7			1.1			0.6
Common shares from conversion of preferred stock		—			12.7			12.8

Changes in Outstanding Common Shares

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

	2019		2018			2017
	(In millions)
Balance at January 1		291.4		315.1			316.5
Conversion of preferred stock		11.6		—			—
Activity related to restricted stock awards, net		0.9		0.8			0.8
Stock options exercised		0.7		0.6			0.2
PSU vested		0.3		0.1			0.2
Shares repurchased		—		(25.2	)		(2.6	)
Balance at December 31		304.9		291.4			315.1

Supplementary Cash Flow Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Flows From Operating Activities
Interest paid	$ (380)	$ (394)	$ (314)
Net income taxes (paid) refunded	(417)	(463)	(210)
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(2,433)	(1,854)	(1,788)
Additions to property, plant and equipment - Midstream	(396)	(243)	(149)
Exploration and Production
Cash Flows From Investing Activities
Capital expenditures incurred	(2,576)	(1,909)	(1,852)
Increase (decrease) in related liabilities	143	55	64
Additions to property, plant and equipment - E&P	(2,433)	(1,854)	(1,788)
Midstream
Cash Flows From Investing Activities
Capital expenditures incurred	(416)	(271)	(121)
Increase (decrease) in related liabilities	20	28	(28)
Additions to property, plant and equipment - Midstream	$ (396)	$ (243)	$ (149)

Inventories (Tables)

12 Months Ended

Dec. 31, 2019

Inventory Disclosure [Abstract]

Inventories

Inventories at December 31 were as follows:

	2019		2018
	(In millions)
Crude oil and natural gas liquids	$	92	$	74
Materials and supplies		169		171
Total Inventories	$	261	$	245

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Income Tax Examination [Line Items]
Gross deferred tax asset related to net operating loss carryforwards	$ 4,733,000,000	$ 4,239,000,000
Gross deferred tax asset related to foreign net operating loss carryforwards	1,447,000,000
Gross deferred tax asset related to net U.S. federal operating loss carryforwards	2,746,000,000
Gross deferred tax asset related to net operating loss carryforwards for various U.S. states	540,000,000
Deferred tax asset related to foreign net operating loss carryforwards, net of valuation allowance	110,000,000
Alternative minimum tax credit carryforwards	49,000,000
Other business credit carryforwards	15,000,000
Foreign tax credit carryforwards - Before valuation allowance	$ 3,000,000
Year in which foreign tax credit carryforwards begin to expire	2021
Valuation allowance against net deferred tax assets	$ 4,734,000,000	4,877,000,000
Unrecognized tax benefits that would impact effective income tax rate	7,000,000
Accrued interest and penalties	7,000,000	$ 3,000,000
Minimum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible	4,000,000
Maximum
Income Tax Examination [Line Items]
Unrecognized tax benefits decrease reasonably possible	$ 11,000,000
Foreign
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 01, 2025
U.S. Federal
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 01, 2034
U.S. State
Income Tax Examination [Line Items]
Operating loss carryforwards expiration date	Jan. 01, 2020

Retirement Plans - Estimated Future Benefit Payments for Funded and Unfunded Pension Plans and Postretirement Medical Plan (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Compensation And Retirement Disclosure [Abstract]
2020	$ 127
2021	126
2022	128
2023	130
2024	133
Years 2025 to 2029	$ 674

Financial Risk Management Activities - Corporate Financial Risk Management Activities - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Derivative Instruments Gain Loss [Line Items]
Cumulative currency translation gain (losses) recognized in earnings	$ 0	$ 0	$ (900,000,000)
Interest Rate Swaps \| Designated as Fair Value Hedges
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	100,000,000	100,000,000
Unrealized change in fair value of interest rate swaps - decrease in derivative liability	(3,000,000)	1,000,000	4,000,000
Amount of terminated interest rate swaps		350,000,000
Payment to terminate interest rate swaps		3,000,000
Foreign Exchange
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	90,000,000	16,000,000
Total foreign exchange gains and (losses) reported in Other, net in Revenues and Non-Operating Income in the Statement of Consolidated Income	3,000,000	(5,000,000)	15,000,000
Gain (Loss) on foreign exchange contracts not designated as hedging instruments	(2,000,000)	(2,000,000)	3,000,000
After tax foreign currency translation adjustments included in Accumulated other comprehensive income (loss)			144,000,000
Cumulative currency translation gain (losses) recognized in earnings			(900,000,000)
Derivative Contracts Designated as Hedging Instruments \| Crude Oil
Derivative Instruments Gain Loss [Line Items]
Increased (decreased) sales and other operating revenue	1,000,000	(161,000,000)	(34,000,000)
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings during the next 12 months	$ (98,000,000)
Derivative Contracts Not Designated as Hedging Instruments \| Crude Oil
Derivative Instruments Gain Loss [Line Items]
Crude oil price hedging contracts decreased sales and other operating revenues by this amount, pre-tax		$ (22,000,000)	$ (25,000,000)

Guarantees, Contingencies and Commitments (Tables)

12 Months Ended

Dec. 31, 2019

Commitments And Contingencies Disclosure [Abstract]

Schedule of Unconditional Purchase Obligations and Commitments

			Payments Due by Period
					2021 and		2023 and
	Total		2020		2022		2024		Thereafter
	(In millions)
Capital expenditures	$	1,743	$	913	$	755	$	75	$	—
Operating expenses		190		158		20		9		3
Transportation and related contracts		1,009		231		424		246		108

Retirement Plans - Amounts Recognized in Consolidated Balance Sheet (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Compensation And Retirement Disclosure [Abstract]
Accumulated other comprehensive (gain) loss related to retirement plans, after-tax - Deficit	$ 601	$ 581

Exit and Disposal Costs - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Restructuring And Related Activities [Abstract]
Severance expense		$ 38	$ 18
Accrued severance costs paid	$ 4	$ 40	$ 48

Leases - Components of Lease Costs (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Leases [Abstract]
Total rental expense	$ 154	$ 123
Income from subleases	$ 8	$ 10

Income Taxes - Components of Income Tax Provision (Benefit) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
United States - Federal, Current income tax expense (benefit)	$ (1)	$ 1	$ (23)
United States - Federal, Deferred income taxes and other accruals expense (benefit)	72	(74)	(6)
United States - State, Current & Deferred income taxes and other accruals expense (benefit)	16	(45)	0
United States, Current & Deferred income taxes and other accruals expense (benefit)	87	(118)	(29)
Current (a)	447	455	179
Foreign, Deferred income taxes and other accruals expense (benefit)	(73)	(2)	(1,987)
Foreign, Current & Deferred income taxes and other accruals expense (benefit)	374	453	(1,808)
Total Provision (Benefit) For Income Taxes	$ 461	$ 335	$ (1,837)

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Changes to Asset Retirement Obligations

The following table describes changes to our asset retirement obligations:

	2019			2018
	(In millions)
Balance at January 1	$	857		$	801
Liabilities incurred		72			68
Liabilities settled or disposed of		(75	)		(46	)
Accretion expense		40			37
Revisions of estimated liabilities		129			1
Foreign currency remeasurement		1			(4	)
Balance at December 31	$	1,024		$	857

Total Asset Retirement Obligations at December 31:
Current portion of asset retirement obligations	$	127		$	116
Long-term asset retirement obligations		897			741
Total at December 31	$	1,024		$	857

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		12 Months Ended
	Dec. 31, 2017	Nov. 30, 2017	Dec. 31, 2017
Disposition Of Businesses [Line Items]
Pre-tax impairment charge			$ 4,203
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)
Pre-tax impairment charge			$ 2,503

Leases - Schedule of Maturities of Lease Obligations (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Leases [Abstract]
Operating Leases, 2020	$ 200
Operating Leases, 2021	72
Operating Leases, 2022	65
Operating Leases, 2023	64
Operating Leases, 2024	65
Operating Leases, Remaining years	133
Total lease payments	599
Less: Imputed interest	(64)
Total lease obligations	535
Finance Leases, 2020	36
Finance Leases, 2021	36
Finance Leases, 2022	36
Finance Leases, 2023	36
Finance Leases, 2024	36
Finance Leases, Remaining years	212
Total lease payments	392
Less: Imputed interest	(137)
Total lease obligations	$ 255

Supplementary Cash Flow Information - Additional Information (Detail) - USD ($)	Dec. 31, 2019	Dec. 16, 2019
Midstream \| Hess Infrastructure Partners LP (HIP)
Supplementary Cash Flow Information [Line Items]
Debt instrument face amount	$ 800,000,000	$ 800,000,000

Disposition

12 Months Ended

Dec. 31, 2019

Disposition Of Businesses [Abstract]

Dispositions

3. Dispositions

2019: We completed the sale of our remaining acreage in the Utica shale play in eastern Ohio for proceeds of $22 million, after normal closing adjustments, and recognized a pre-tax gain of $22 million ($22 million after income taxes).

2018: We 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 interests). 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 included the recognition of cumulative translation adjustments totaling $900 million in earnings 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).

	2019		2018		2017
	(In millions)
Equatorial Guinea (a)	$	—	$	—	$	69
Norway (b)		—		—		(55	)
Income (Loss) from Continuing Operations Before Income Taxes	$	—	$	—	$	14

(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.

Retirement Plans (Tables)

12 Months Ended

Dec. 31, 2019

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
	2019			2018			2019			2018			2019			2018
	(In millions)
Change in Benefit Obligation
Balance at January 1,	$	2,492		$	2,765		$	216		$	249		$	59		$	87
Service cost		33			30			11			12			2			2
Interest cost		82			84			7			7			2			3
Actuarial (gains) loss (a)		401			(237	)		22			(29	)		19			(24	)
Single premium annuity contract payment		(249	)		—			—			—			—			—
Benefit payments (b)		(113	)		(110	)		(14	)		(19	)		(7	)		(7	)
Plan curtailments		—			(10	)		—			(4	)		—			(2	)
Plan amendments		—			4			—			—			—			—
Foreign currency exchange rate changes		21			(34	)		—			—			—			—
Balance at December 31, (c)		2,667			2,492			242			216			75			59
Change in Fair Value of Plan Assets
Balance at January 1,	$	2,568		$	2,732		$	—		$	—		$	—		$	—
Actual return on plan assets		462			(77	)		—			—			—			—
Employer contributions		40			59			14			19			7			7
Single premium annuity contract payment		(249	)		—			—			—			—			—
Benefit payments (b)		(113	)		(110	)		(14	)		(19	)		(7	)		(7	)
Foreign currency exchange rate changes		24			(36	)		—			—			—			—
Balance at December 31,		2,732			2,568			—			—			—			—

Funded Status (Plan assets greater (less) than benefit obligations) at December 31,	$	65		$	76		$	(242	)	$	(216	)	$	(75	)	$	(59	)

Unrecognized Net Actuarial (Gains) Losses	$	756		$	778		$	65		$	47		$	(12	)	$	(32	)

(a)	Changes in discount rates resulted in actuarial losses of approximately $465 million in 2019 (2018: $235 million of actuarial gains from changes in discount rates).

(b)	Benefit payments include lump-sum settlement payments of approximately $27 million in 2019 (2018: $32 million).

(c)	At December 31, 2019, the accumulated benefit obligation for the funded and unfunded defined benefit pension plans was $2,580 million and $194 million, respectively (2018: $2,424 million and $171 million, respectively).

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
	2019			2018		2019			2018			2019			2018
	(In millions)
Noncurrent assets	$	71		$	76	$	—		$	—		$	—		$	—
Current liabilities		—			—		(32	)		(30	)		(8	)		(9	)
Noncurrent liabilities		(6	)		—		(210	)		(186	)		(67	)		(50	)
Pension assets / (accrued benefit liability)	$	65		$	76	$	(242	)	$	(216	)	$	(75	)	$	(59	)

Accumulated other comprehensive loss, pre-tax (a)	$	756		$	778	$	65		$	47		$	(12	)	$	(32	)

(a)	The after‑tax deficit reflected in Accumulated other comprehensive income (loss) was $601 million at December 31, 2019 (2018: $581 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
	2019			2018			2017			2019			2018			2017
	(In millions)
Service cost	$	44		$	42		$	49		$	2		$	2		$	4
Interest cost		89			91			102			2			3			3
Expected return on plan assets		(180	)		(194	)		(168	)		—			—			—
Amortization of unrecognized net actuarial losses (gains)		52			39			58			(1	)		(2	)		—
Settlement loss		93			4			19			—			—			—
Curtailment gain		—			—			—			—			(2	)		—
Net Periodic Benefit Cost (a)	$	98		$	(18	)	$	60		$	3		$	1		$	7

(a)	Net non-service pension costs are included in Other, net in the Statement of Consolidated Income. In 2019, net non-service pension costs amounted to an expense of $55 million (2018: $61 million of income; 2017: $14 million of expense).

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:

	2019			2018			2017
Benefit Obligations:
Discount rate		2.9	%		3.9	%		3.3	%
Rate of compensation increase		3.8	%		3.8	%		4.5	%

Net Periodic Benefit Cost:
Discount rate
Service cost		3.9	%		3.9	%		3.7	%
Interest cost		3.4	%		3.3	%		3.7	%
Expected return on plan assets		7.1	%		7.2	%		7.3	%
Rate of compensation increase		3.8	%		4.5	%		4.6	%

The actuarial assumptions used to determine Benefit obligations at December 31 for the postretirement medical plan were as follows:

	2019			2018			2017

Discount rate		2.8	%		3.9	%		3.2	%
Initial health care trend rate		6.5	%		6.9	%		7.3	%
Ultimate trend rate		4.5	%		4.5	%		4.5	%
Year in which ultimate trend rate is reached		2038			2038			2038

Fair Value of Financial Assets of Funded Pension Plans

	Level 1		Level 2		Level 3		Net Asset Value (d)		Total
	(In millions)
December 31, 2019
Cash and Short-Term Investment Funds	$	57	$	—	$	—	$	—	$	57
Equities:
U.S. equities (domestic)		638		—		—		—		638
International equities (non-U.S.)		80		37		—		302		419
Global equities (domestic and non-U.S.)		—		8		—		196		204
Fixed Income:
Treasury and government issued (a)		—		210		—		—		210
Government related (b)		—		162		—		56		218
Mortgage-backed securities (c)		—		141		—		30		171
Corporate		—		293		—		82		375
Other:
Hedge funds		—		—		—		65		65
Private equity funds		—		—		—		191		191
Real estate funds		27		—		—		157		184
Total investments	$	802	$	851	$	—	$	1,079	$	2,732

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		—		—		111		160
Diversified commodities funds		—		19		—		—		19
Total investments	$	800	$	1,006	$	—	$	762	$	2,568

(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)

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):

2020	$	127
2021		126
2022		128
2023		130
2024		133
Years 2025 to 2029		674

Debt - Maturity Profile of Total Debt (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
2020	$ 0
2021	10
2022	20
2023	30
2024	672
Thereafter	6,488
Total Borrowings	7,220
Less: Deferred issuance costs	(78)
Total Debt (excluding interest)	7,142
Midstream
Debt Instrument [Line Items]
2020	0
2021	10
2022	20
2023	30
2024	372
Thereafter	1,350
Total Borrowings	1,782
Less: Deferred issuance costs	(29)
Total Debt (excluding interest)	1,753
Hess Corporation
Debt Instrument [Line Items]
2020	0
2021	0
2022	0
2023	0
2024	300
Thereafter	5,138
Total Borrowings	5,438
Less: Deferred issuance costs	(49)
Total Debt (excluding interest)	$ 5,389

Leases - Components of Lease Costs (Detail) $ in Millions	12 Months Ended
Leases - Components of Lease Costs (Detail) $ in Millions	Dec. 31, 2019 USD ($)
Leases [Abstract]
Operating lease cost	$ 414
Finance lease cost:
Amortization of leased assets	43
Interest on lease obligations	21
Short-term lease cost	164
Variable lease cost	89
Sublease income	(12)
Total lease cost	$ 719

Financial Risk Management Activities - Credit Risk - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Letters of credit – Issued	$ 272	$ 284
Integrated Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	41.00%
Independent E&P Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	26.00%
National Oil Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	8.00%
Storage and Transportation Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	5.00%
Refining and Marketing Companies
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	14.00%
Others
Fair Value Concentration Of Risk Financial Statement Captions [Line Items]
Accounts receivable - Trade	6.00%

Revenue (Tables)

12 Months Ended

Dec. 31, 2019

Revenue From Contract With Customer [Abstract]

Summary of Revenue from Contracts with Customers on a Disaggregated Basis

Revenue from contracts with customers on a disaggregated basis was as follows (in millions):

	Exploration and Production												Midstream		Eliminations			Total
	United States			Europe		Africa		Asia		E&P Total
2019
Sales of our net production volumes:
Crude oil revenue	$	2,981		$	130	$	436	$	113	$	3,660		$	—	$	—		$	3,660
Natural gas liquids revenue		229			—		—		—		229			—		—			229
Natural gas revenue		150			9		24		646		829			—		—			829
Sales of purchased oil and gas		1,644			—		91		3		1,738			—		—			1,738
Intercompany revenue		—			—		—		—		—			848		(848	)		—
Total revenues from contracts with customers		5,004			139		551		762		6,456			848		(848	)		6,456
Other operating revenues (a)		39			—		—		—		39			—		—			39
Total sales and other operating revenues	$	5,043		$	139	$	551	$	762	$	6,495		$	848	$	(848	)	$	6,495

	Exploration and Production												Midstream		Eliminations			Total
	United States			Europe		Africa		Asia		E&P Total
2018
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.

Guarantees, Contingencies and Commitments - Additional Information (Detail) $ in Millions		1 Months Ended
	Mar. 04, 2016 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2019 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

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2019

Property Plant And Equipment [Abstract]

Property, Plant and Equipment

5. Property, Plant and Equipment

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

	2019		2018
	(In millions)
Exploration and Production
Unproved properties	$	168	$	394
Proved properties		3,304		3,124
Wells, equipment and related facilities		28,404		26,173
		31,876		29,691
Midstream		3,904		3,492
Corporate and Other		40		39
Total — at cost		35,820		33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment		19,006		17,139
Property, Plant and Equipment — Net	$	16,814	$	16,083

	2019			2018			2017
	(In millions)
Balance at January 1	$	418		$	304		$	597
Additions to capitalized exploratory well costs pending the determination of proved reserves		224			128			116
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(58	)		—			(165	)
Capitalized exploratory well costs charged to expense		—			(14	)		(268	)
Dispositions and other		—			—			24
Balance at December 31	$	584		$	418		$	304
Number of Wells at December 31		31			24			12

During the three years ended December 31, 2019, additions to capitalized exploratory well costs primarily related to drilling at the Stabroek Block, offshore Guyana. Other drilling activity included the Esox prospect in the Gulf of Mexico during 2019 and the Bunga prospect in Malaysia during 2018. Reclassifications to wells, facilities and equipment based on the determination of proved reserves in 2019 primarily related to the Stabroek Block, offshore Guyana, where the Liza Phase 2 development was sanctioned and the Esox discovery. In 2017, the Liza Phase 1 development was sanctioned.

Capitalized exploratory well costs included in the table above that were 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 was 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 we would not develop the previously discovered fields. As a result, we recorded a charge of $268 million to write-off previously capitalized exploration wells.

The preceding table excludes well costs incurred and expensed during 2019 of $49 million (2018: $151 million; 2017: $0 million).

Exploratory well costs capitalized for greater than one year following completion of drilling were $400 million at December 31, 2019, separated by year of completion as follows (in millions):

2018	$	157
2017		73
2016		—
2015		166
2014 and prior		4
	$	400

Guyana: Approximately 50% of the capitalized well costs in excess of one year relates to ten successful exploration wells where hydrocarbons were encountered on the Stabroek Block, offshore Guyana. The operator plans further appraisal drilling for certain fields and is conducting pre-development planning for additional phases of development beyond the two existing sanctioned phases of development.

Gulf of Mexico: Approximately 30% of the capitalized well costs in excess of one year relates to the appraisal of the northern portion of the Shenzi Field (Hess 28%) 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 commenced acquiring 3D seismic in 2019 for use in ongoing appraisal and development planning of the northern portion of the Shenzi Field.

JDA: Approximately 10% 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 ongoing commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block.

Malaysia: Approximately 10% 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 five successful exploration wells. We are continuing with pre-development planning for future phases of field development.

Segment Information (Tables)

12 Months Ended

Dec. 31, 2019

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
2019
Sales and Other Operating Revenues - Third parties	$	6,495		$	—	$	—		$	—		$	6,495
Intersegment Revenues		—			848		—			(848	)		—
Sales and Other Operating Revenues	$	6,495		$	848	$	—		$	(848	)	$	6,495

Net Income (Loss) Attributable to Hess Corporation	$	53		$	144	$	(605	)	$	—		$	(408	)
Interest Expense		—			63		317			—			380
Depreciation, Depletion and Amortization		1,977			142		3			—			2,122
Provision (Benefit) for Income Taxes (a)		375			—		86			—			461
Investment in Affiliates		114			108		—			—			222
Identifiable Assets		16,790			3,499		1,493			—			21,782
Capital Expenditures		2,576			416		—			—			2,992

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	)
Capital Expenditures		1,852			121		—			—			1,973

(a)

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)
2019
Sales and Other Operating Revenues	$	5,043		$	139		$	551	$	762		$	—		$	6,495
Net Income (Loss) Attributable to Hess Corporation		15			2			36		144			(605	)		(408	)
Depreciation, Depletion and Amortization		1,631			53			21		414			3			2,122
Provision (Benefit) for Income Taxes		—			1			425		(51	)		86			461
Identifiable Assets		14,234			1,070			399		4,586			1,493			21,782
Property, Plant and Equipment (Net)		12,182			871			350		3,399			12			16,814
Capital Expenditures		2,094			40			15		843			—			2,992

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	)
Capital Expenditures		1,387			141			30		415			—			1,973

Share-based Compensation - Summary of PSU Activity (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Performance Share Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value of vested shares	$ 16	$ 9	$ 10

Asset Retirement Obligations - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Fair value of sinking fund deposits legally restricted for purposes of settling asset retirement obligations	$ 178	$ 148

Share-based Compensation - Summary of Restricted Stock Award Activity (Detail) - Restricted Stock shares in Thousands	12 Months Ended
	Dec. 31, 2019 $ / shares shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards - Outstanding at beginning of period \| shares	2,881
Awards - Granted \| shares	965
Awards - Vested \| shares	(1,742)
Awards - Forfeited \| shares	(90)
Awards - Outstanding at end of period \| shares	2,014
Weighted average fair value on date of grant - Outstanding at beginning of period \| $ / shares	$ 48.70
Weighted average fair value on date of grant - Granted \| $ / shares	56.87
Weighted average fair value on date of grant - Vested \| $ / shares	47.35
Weighted average fair value on date of grant - Forfeited \| $ / shares	52.67
Weighted average fair value on date of grant - Outstanding at end of period \| $ / shares	$ 53.61

Segment Information - Financial Information by Major Geographic Area (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 6,495	$ 6,323	$ 5,466
Net Income (Loss) Attributable to Hess Corporation	(408)	(282)	(4,074)
Depreciation, Depletion and Amortization	2,122	1,883	2,883
Impairment			4,203
Provision (benefit) for income taxes	461	335	(1,837)
Identifiable Assets	21,782	21,433
Property, Plant and Equipment (Net)	16,814	16,083
Capital Expenditures	2,992	2,180	1,973
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	(605)	(453)	(463)
Depreciation, Depletion and Amortization	3	8	24
Impairment			0
Provision (benefit) for income taxes	86	(94)	(26)
Identifiable Assets	1,493	2,039
Property, Plant and Equipment (Net)	12	15
Capital Expenditures	0	0	0
United States
Segment Reporting Information [Line Items]
Sales and other operating revenues	5,043	4,842	3,692
Net Income (Loss) Attributable to Hess Corporation	15	131	(2,433)
Depreciation, Depletion and Amortization	1,631	1,424	1,942
Impairment			1,700
Provision (benefit) for income taxes	0	(25)	0
Identifiable Assets	14,234	13,250
Property, Plant and Equipment (Net)	12,182	11,653
Capital Expenditures	2,094	1,543	1,387
Europe \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	139	164	629
Net Income (Loss) Attributable to Hess Corporation	2	42	(1,383)
Depreciation, Depletion and Amortization	53	37	381
Impairment			2,503
Provision (benefit) for income taxes	1	15	(1,999)
Identifiable Assets	1,070	1,033
Property, Plant and Equipment (Net)	871	906
Capital Expenditures	40	8	141
Africa \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	551	548	675
Net Income (Loss) Attributable to Hess Corporation	36	36	259
Depreciation, Depletion and Amortization	21	19	263
Impairment			0
Provision (benefit) for income taxes	425	430	197
Identifiable Assets	399	395
Property, Plant and Equipment (Net)	350	355
Capital Expenditures	15	9	30
Asia and Other Countries \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	762	769	470
Net Income (Loss) Attributable to Hess Corporation	144	(38)	(54)
Depreciation, Depletion and Amortization	414	395	273
Impairment			0
Provision (benefit) for income taxes	(51)	9	(9)
Identifiable Assets	4,586	4,716
Property, Plant and Equipment (Net)	3,399	3,154
Capital Expenditures	$ 843	$ 620	$ 415

Debt - Other Outstanding Letters of Credit (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2019
Committed and Uncommitted Lines
Line Of Credit Facility [Line Items]
Maturity year	2020

Retirement Plans - Fair Value of Financial Assets of Funded Pension Plans (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 2,732	$ 2,568
Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	57	50
U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	638	654
International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	419	409
Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	204	205
Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	210	240
Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	218	37
Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	171	186
Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	375	303
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	65	135
Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	191	170
Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	184	160
Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans		19
Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	802	800
Level 1 \| Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	57	3
Level 1 \| U.S. Equities (domestic)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	638	654
Level 1 \| International Equities (non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	80	92
Level 1 \| Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	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	27	49
Level 1 \| Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans		0
Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	851	1,006
Level 2 \| Cash and Short-term Investment Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	47
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	37	29
Level 2 \| Global Equities (domestic and non-U.S.)
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	8	203
Level 2 \| Treasury and Government Issued - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	210	240
Level 2 \| Government Related - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	162	37
Level 2 \| Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	141	159
Level 2 \| Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	293	272
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
Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
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	0
Level 3 \| Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	0	0
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	0	0
Level 3 \| Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans		0
Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	1,079	762
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	302	288
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	196	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	56	0
Net Asset Value \| Mortgage-backed Securities - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	30	27
Net Asset Value \| Corporate - Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	82	31
Net Asset Value \| Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	65	135
Net Asset Value \| Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	191	170
Net Asset Value \| Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans	$ 157	111
Net Asset Value \| Diversified Commodities Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of financial assets of funded pension plans		$ 0