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Document and Entity Information	3 Months Ended
Document and Entity Information	Mar. 31, 2019 shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	HES
Entity Registrant Name	HESS CORP
Entity Central Index Key	0000004447
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding	304,280,819

Consolidated Balance Sheet - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 2,300	$ 2,694
Accounts receivable:
From contracts with customers	868	771
Joint venture and other	248	230
Inventories	274	245
Other current assets	144	519
Total current assets	3,834	4,459
Property, plant and equipment:
Total — at cost	33,446	33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment	17,548	17,139
Property, plant and equipment — net	15,898	16,083
Operating lease right-of-use assets — net	713	0
Finance lease right-of-use assets — net	332	0
Goodwill	360	360
Deferred income taxes	22	21
Other assets	557	510
Total Assets	21,716	21,433
Current Liabilities:
Accounts payable	399	495
Accrued liabilities	1,369	1,560
Taxes payable	89	81
Current maturities of long-term debt	12	67
Current portion of operating and finance lease obligations	402	0
Total current liabilities	2,271	2,203
Long-term debt	6,550	6,605
Long-term operating lease obligations	436	0
Long-term finance lease obligations	250	0
Deferred income taxes	420	421
Asset retirement obligations	745	741
Other liabilities and deferred credits	491	575
Total Liabilities	11,163	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 - 0 shares (2018: 574,997)	0	1
Common stock, par value $1.00; Authorized -600,000,000 shares; Issued - 304,280,819 shares (2018: 291,434,534)	304	291
Capital in excess of par value	5,481	5,386
Retained earnings	4,207	4,257
Accumulated other comprehensive income (loss)	(650)	(306)
Total Hess Corporation stockholders’ equity	9,342	9,629
Noncontrolling interests	1,211	1,259
Total equity	10,553	10,888
Total Liabilities and Equity	$ 21,716	$ 21,433

Consolidated Balance Sheet (Parenthetical) - $ / shares	3 Months Ended	12 Months Ended
Consolidated Balance Sheet (Parenthetical) - $ / shares	Mar. 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	304,280,819	291,434,534

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Revenues and Non-Operating Income
Sales and other operating revenues	$ 1,572	$ 1,346
Gains on asset sales, net	0	7
Other, net	27	37
Total revenues and non-operating income	1,599	1,390
Costs and Expenses
Marketing, including purchased oil and gas	408	358
Operating costs and expenses	266	288
Production and severance taxes	39	39
Exploration expenses, including dry holes and lease impairment	34	40
General and administrative expenses	87	110
Interest expense	98	103
Loss on debt extinguishment	0	27
Depreciation, depletion and amortization	498	417
Total costs and expenses	1,430	1,382
Income (Loss) Before Income Taxes	169	8
Provision (benefit) for income taxes	94	73
Net Income (Loss)	75	(65)
Less: Net income (loss) attributable to noncontrolling interests	43	41
Net Income (Loss) Attributable to Hess Corporation	32	(106)
Less: Preferred stock dividends	4	11
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ 28	$ (117)
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$ 0.09	$ (0.38)
Diluted	$ 0.09	$ (0.38)
Weighted Average Number of Common Shares Outstanding:
Basic	297.4	309.5
Diluted	299.7	309.5
Common Stock Dividends Per Share	$ 0.25	$ 0.25

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ 75	$ (65)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	(15)	31
Income taxes on effect of hedge (gains) losses reclassified to income	0	0
Net effect of hedge (gains) losses reclassified to income	(15)	31
Change in fair value of cash flow hedges	(346)	(22)
Income taxes on change in fair value of cash flow hedges	0	0
Net change in fair value of cash flow hedges	(346)	(22)
Change in derivatives designated as cash flow hedges, after taxes	(361)	9
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	6	125
Income taxes on actuarial changes in plan liabilities	0	(30)
(Increase) reduction in unrecognized actuarial losses, net	6	95
Amortization of net actuarial losses	11	12
Income taxes on amortization of net actuarial losses	0	0
Net effect of amortization of net actuarial losses	11	12
Change in pension and other postretirement plans, after taxes	17	107
Other Comprehensive Income (Loss)	(344)	116
Comprehensive Income (Loss)	(269)	51
Less: Comprehensive income (loss) attributable to noncontrolling interests	43	41
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (312)	$ 10

Statement of Consolidated Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Cash Flows From Operating Activities
Net income (loss)	$ 75	$ (65)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Gains on asset sales, net	0	(7)
Depreciation, depletion and amortization	498	417
Exploration lease and other impairment	7	10
Stock compensation expense	27	13
Noncash (gains) losses on commodity derivatives, net	29	38
Provision (benefit) for deferred income taxes and other tax accruals	(1)	(36)
Loss on debt extinguishment	0	27
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(117)	(11)
(Increase) decrease in inventories	(29)	(7)
Increase (decrease) in accounts payable and accrued liabilities	(204)	(135)
Increase (decrease) in taxes payable	8	(1)
Changes in other operating assets and liabilities	(55)	(33)
Net cash provided by (used in) operating activities	238	210
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(521)	(363)
Additions to property, plant and equipment - Midstream	(150)	(37)
Payments for Midstream equity investments	(7)	(24)
Proceeds from asset sales, net of cash sold	0	6
Other, net	(2)	(4)
Net cash provided by (used in) investing activities	(680)	(422)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	199	0
Debt with maturities of greater than 90 days – Repayments	(3)	(434)
Payments on finance lease obligations	(23)	0
Common stock acquired and retired	(25)	(371)
Cash dividends paid	(88)	(89)
Noncontrolling interests, net	(13)	(12)
Other, net	1	(3)
Net cash provided by (used in) financing activities	48	(909)
Net Increase (Decrease) in Cash and Cash Equivalents	(394)	(1,121)
Cash and Cash Equivalents at Beginning of Year	2,694	4,847
Cash and Cash Equivalents at End of Period	$ 2,300	$ 3,726

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, 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	1	(1)	0	0
Net income (loss)	(65)	0	0	0	(106)	0	(106)	41
Other comprehensive income (loss)	116	0	0	0	0	116	116	0
Share-based compensation activity	13	0	1	12	0	0	13	0
Dividends on preferred stock	(11)	0	0	0	(11)	0	(11)	0
Dividends on common stock	(78)	0	0	0	(78)	0	(78)	0
Common stock acquired and retired	(380)	0	(8)	(135)	(237)	0	(380)	0
Noncontrolling interests, net	(12)	0	0	0	0	0	0	(12)
Balance at Mar. 31, 2018	11,937	1	308	5,701	5,166	(571)	10,605	1,332
Balance at Dec. 31, 2018	10,888	1	291	5,386	4,257	(306)	9,629	1,259
Net income (loss)	75	0	0	0	32	0	32	43
Other comprehensive income (loss)	(344)	0	0	0	0	(344)	(344)	0
Preferred stock conversion	0	(1)	12	(11)	0	0	0	0
Share-based compensation activity	29	0	1	28	0	0	29	0
Dividends on preferred stock	(4)	0	0	0	(4)	0	(4)	0
Dividends on common stock	(78)	0	0	0	(78)	0	(78)	0
Sale of water business to Hess Infrastructure Partners	0	0	0	78	0	0	78	(78)
Noncontrolling interests, net	(13)	0	0	0	0	0	0	(13)
Balance at Mar. 31, 2019	$ 10,553	$ 0	$ 304	$ 5,481	$ 4,207	$ (650)	$ 9,342	$ 1,211

Basis of Presentation

3 Months Ended

Mar. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Basis of Presentation

1. Basis of Presentation

The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of our consolidated financial position at March 31, 2019 and December 31, 2018, the consolidated results of operations for the three months ended March 31, 2019 and 2018, and consolidated cash flows for the three months ended March 31, 2019 and 2018. The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year.

The financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (SEC) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by generally accepted accounting principles (GAAP) in the United States have been condensed or omitted from these interim financial statements. These statements, therefore, should be read in conjunction with the consolidated financial statements and related notes included in the Corporation’s Annual Report on Form 10-K for the year ended December 31, 2018.

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 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 right-of-use 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

New Accounting Pronouncements: In June 2016, the FASB issued Accounting Standards Update (ASU) 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared to the current "incurred loss" model. We expect to adopt this ASU in the first quarter of 2020 when the standard becomes effective. We continue to evaluate this ASU but do not believe it will have a material impact on our Consolidated Financial Statements.

Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases

2. Leases

We determine if an arrangement is an operating lease or a finance lease at inception by evaluating whether the contract conveys the right to control an identified asset during the period of use. Right-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 liabilities are recognized in the Consolidated Balance Sheet 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 March 31, 2019 were as follows:

	Operating Leases		Finance Leases
	(In millions)
Right-of-use assets — net (a)	$	713	$	332
Lease obligations:
Current	$	366	$	36
Long-term		436		250
Total lease obligations	$	802	$	286

(a)	Finance lease Right-of-use assets have a cost of $384 million and accumulated amortization of $52 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 March 31, 2019 was as follows:

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

Finance leases: In 2018, we entered into a sale and lease-back arrangement for a floating storage and offloading vessel (FSO) to handle produced condensate at North Malay Basin, offshore Peninsular Malaysia (Hess operated – 50%). No gain or loss was recognized from the sale transaction. The remaining lease term utilized in the lease obligation is 14.5 years. At March 31, 2019, the carrying value of the Finance lease asset is $256 million and the carrying value of the Finance lease obligation is $266 million. We have another finance lease obligation of $20 million at March 31, 2019 that will be settled in the second quarter of 2019.

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

	Operating Leases			Finance Leases
	(In millions)
2019	$	308		$	48
2020		183			36
2021		71			36
2022		64			36
2023		64			36
Remaining years		197			248
Total lease payments		887			440
Less: Imputed interest		(85	)		(154	)
Total lease obligations	$	802		$	286

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

	Operating Leases	Finance Leases
Weighted average remaining lease term	4.7 years	13.5 years
Range of remaining lease terms	0.1 - 9.3 years	0.2 - 14.5 years
Weighted average discount rate	4.3%	7.8%

The components of lease costs in the first quarter of 2019 were as follows (in millions):

Operating lease cost	$	103
Finance lease cost:
Amortization of leased assets		13
Interest on lease obligations		6
Short-term lease cost (a)		32
Variable lease cost (b)		19
Sublease income (c)		(3	)
Total lease cost	$	170

(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.

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 first quarter of 2019 was as follows:

	Operating Leases		Finance Leases
	(In millions)
Cash paid for amounts included in the measurement of lease obligations:
Operating cash flows	$	106	$	6
Financing cash flows		—		23
Noncash transactions:
Leased assets recognized for new lease obligations incurred	3			—

Preferred Stock Conversion

3 Months Ended

Mar. 31, 2019

Stockholders Equity Note [Abstract]

Preferred Stock Conversion

3. Preferred Stock Conversion

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

Revenue

3 Months Ended

Mar. 31, 2019

Revenue From Contract With Customer [Abstract]

Revenue

4. Revenue

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

	Exploration and Production												Midstream		Eliminations			Total
	United States			Denmark		Libya		Malaysia & JDA		E&P Total
Three Months Ended March 31, 2019
Sales of our net production volumes:
Crude oil revenue	$	682		$	16	$	91	$	21	$	810		$	—	$	—		$	810
Natural gas liquids revenue		68			—		—		—		68			—		—			68
Natural gas revenue		42			3		6		180		231			—		—			231
Sales of purchased oil and gas		426			—		22		—		448			—		—			448
Intercompany revenue		—			—		—		—		—			190		(190	)		—
Total revenues from contracts with customers		1,218			19		119		201		1,557			190		(190	)		1,557
Other operating revenues (a)		15			—		—		—		15			—		—			15
Total sales and other operating revenues	$	1,233		$	19	$	119	$	201	$	1,572		$	190	$	(190	)	$	1,572

Three Months Ended March 31, 2018
Sales of our net production volumes:
Crude oil revenue	$	593		$	33	$	99	$	43	$	768		$	—	$	—		$	768
Natural gas liquids revenue		71			—		—		—		71			—		—			71
Natural gas revenue		39			3		8		128		178			—		—			178
Sales of purchased oil and gas		325			—		24		14		363			—		—			363
Intercompany revenue		—			—		—		—		—			167		(167	)		—
Total revenues from contracts with customers		1,028			36		131		185		1,380			167		(167	)		1,380
Other operating revenues (a)		(34	)		—		—		—		(34	)		—		—			(34	)
Total sales and other operating revenues	$	994		$	36	$	131	$	185	$	1,346		$	167	$	(167	)	$	1,346

(a)	Includes gains (losses) on commodity derivatives.

There have been no significant changes to contracts with customers or composition thereof during the first quarter of 2019. Generally, we receive payments from customers on a monthly basis, shortly after the physical delivery of the crude oil, NGLs, or natural gas. We did not recognize any credit losses on receivables with customers in the first quarter of 2019 or 2018.

Inventories

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Inventories

5. Inventories

Inventories consisted of the following:

	March 31,		December 31,
	2019		2018
	(In millions)
Crude oil and natural gas liquids	$	96	$	74
Materials and supplies		178		171
Total Inventories	$	274	$	245

Capitalized Exploratory Well Costs

3 Months Ended

Mar. 31, 2019

Capitalized Exploratory Well Costs [Abstract]

Capitalized Exploratory Well Costs

6. Capitalized Exploratory Well Costs

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the three months ended March 31, 2019 (in millions):

Balance at January 1, 2019	$	418
Additions to capitalized exploratory well costs pending the determination of proved reserves		48
Balance at March 31, 2019	$	466

Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $309 million at March 31, 2019 and primarily related to:

Guyana: Approximately 45% of the capitalized well costs in excess of one year relates to the Liza-4, Pacora-1, Payara-1, Payara-2, Ranger-1 and Snoek-1 wells on the Stabroek Block, offshore Guyana (Hess 30%), where hydrocarbons were encountered. The operator plans to integrate the Liza-4 discovery into the second phase of development, which is expected to commence production by mid-2022. The operator plans to integrate the Pacora-1, Payara-1 and Payara-2 discoveries into the third phase of development, which is expected to commence production as early as 2023. The Snoek discovery is expected to produce into the Liza Phase 1 floating, production storage and offloading (FPSO) vessel under a subsequent phase of development, and the operator is planning further drilling at the Ranger discovery.

Gulf of Mexico: Approximately 40% 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 is planning to acquire 3D seismic in 2019 for use in 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 commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block.

Malaysia: Approximately 5% of the capitalized well costs in excess of one year relates to the North Malay Basin, offshore Peninsular Malaysia (Hess 50%), where hydrocarbons were encountered in one successful exploration well drilled in the fourth quarter of 2015. In 2018, we completed four exploration wells and are conducting subsurface evaluations for consideration in future phases of field development.

Hess Infrastructure Partners LP

3 Months Ended

Mar. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Hess Infrastructure Partners LP

7. Hess Infrastructure Partners LP

We consolidate the activities of Hess Infrastructure Partners LP (HIP), a 50/50 joint venture between Hess Corporation and Global Infrastructure Partners (GIP), which qualifies as a variable interest entity (VIE) under U.S. GAAP. We have concluded that we are the primary beneficiary of the VIE, as defined in the accounting standards, since we have the power, through our 50% ownership, to direct those activities that most significantly impact the economic performance of HIP.

As of March 31, 2019, the Midstream segment is comprised of HIP, which owns the general partner of Hess Midstream Partners LP (HESM). HESM owns an approximate 20% controlling interest in the operating companies that comprise our midstream joint venture while HIP owns the remaining 80%, other than the water services business that is wholly owned by HIP as described below. At March 31, 2019, HIP liabilities totaling $1,273 million (December 31, 2018: $1,105 million) are on a nonrecourse basis to Hess Corporation, while HIP assets available to settle the obligations of HIP include cash and cash equivalents totaling $6 million (December 31, 2018: $109 million) and property, plant and equipment with a carrying value of $2,829 million (December 31, 2018: $2,664 million).

On March 1, 2019, HIP completed the acquisition of Hess’ 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 HESM 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.

Retirement Plans

3 Months Ended

Mar. 31, 2019

Compensation And Retirement Disclosure [Abstract]

Retirement Plans

8. Retirement Plans

Components of net periodic pension cost consisted of the following:

	Three Months Ended
	March 31,
	2019			2018
	(In millions)
Service cost	$	10		$	14
Interest cost (a)		24			23
Expected return on plan assets (a)		(45	)		(49	)
Amortization of unrecognized net actuarial losses (a)		11			12
Curtailment gains (a)		—			(2	)
Pension (income) expense (a)	$	—		$	(2	)

(a) Net non-service pension cost included in Other, net in the Statement of Consolidated Income in the first quarter of 2019 was income of $10 million (2018: $16 million of income).

In 2019, we expect to contribute $40 million to our funded pension plans. Through March 31, 2019, we have contributed $10 million.

Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Debt

9. Debt

In the first quarter of 2019, HIP and HESM borrowed a total of $199 million from their revolving credit facilities. In the first quarter of 2018, we paid $415 million to redeem $350 million principal amount of 8.125% notes due 2019 with a carrying value of $349 million at December 31, 2017, and to purchase other notes with a carrying value of $38 million at December 31, 2017. Concurrent with the redemption of the 2019 notes, we terminated interest rate swaps with a notional amount of $350 million. First quarter 2018 results included a pre-tax charge of $27 million for the loss on extinguishment of the redeemed and purchased notes.

Weighted Average Common Shares

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Weighted Average Common Shares

10. Weighted Average Common Shares

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

	Three Months Ended
	March 31,
	2019		2018
	(In millions)
Net income (loss) attributable to Hess Corporation Common Stockholders:

Net income (loss)	$	75	$	(65	)
Less: Net income (loss) attributable to noncontrolling interests		43		41
Less: Preferred stock dividends		4		11
Net income (loss) attributable to Hess Corporation Common Stockholders	$	28	$	(117	)

Weighted average number of common shares outstanding:

Basic		297.4		309.5
Effect of dilutive securities
Restricted common stock		1.2		—
Stock options		0.2		—
Performance share units		0.9		—
Diluted		299.7		309.5

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

	Three Months Ended
	March 31,
	2019		2018
Restricted common stock		57,252		2,922,316
Stock options		3,394,418		5,807,579
Performance share units		65,661		623,088
Common shares from conversion of preferred stocks		3,930,663		12,584,974

During the first quarter of 2019, we granted 941,082 shares of restricted stock (2018: 1,081,923), 234,866 performance share units (2018: 278,003) and 526,968 stock options (2018: 683,167).

Guarantees and Contingencies

3 Months Ended

Mar. 31, 2019

Commitments And Contingencies Disclosure [Abstract]

Guarantees and Contingencies

11. Guarantees and Contingencies

We are subject to loss contingencies with respect to various claims, lawsuits and other proceedings. A liability is recognized in our consolidated financial statements when it is probable that a loss has been incurred and the amount can be reasonably estimated. If the risk of loss is probable, but the amount cannot be reasonably estimated or the risk of loss is only reasonably possible, a liability is not accrued; however, we disclose the nature of those contingencies. We cannot predict with certainty if, how or when existing claims, lawsuits and proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages. Numerous issues may need to be resolved, including through lengthy discovery, conciliation and/or arbitration proceedings, or litigation before a loss or range of loss can be reasonably estimated. Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of such lawsuits, claims and proceedings, including the matters described below, is not expected to have a material adverse effect on our financial condition. However, we could incur judgments, enter into settlements, or revise our opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations in the period in which the amounts are accrued and our cash flows in the period in which the amounts are paid.

We, along with many companies that have been or continue to be engaged in refining and marketing of gasoline, have been a party to lawsuits and claims related to the use of methyl tertiary butyl ether (MTBE) in gasoline. A series of similar lawsuits, many involving water utilities or governmental entities, were filed in jurisdictions across the U.S. against producers of MTBE and petroleum refiners who produced gasoline containing MTBE, including us. The principal allegation in all cases was that gasoline containing MTBE was a defective product and that these producers and refiners are strictly liable in proportion to their share of the gasoline market for damage to groundwater resources and are required to take remedial action to ameliorate the alleged effects on the environment of releases of MTBE. The majority of the cases asserted against us have been settled. There are three remaining active cases, filed by Pennsylvania, Rhode Island, and Maryland. In June 2014, the Commonwealth of Pennsylvania filed a lawsuit alleging that we and all major oil companies with operations in Pennsylvania, have damaged the groundwater by introducing thereto gasoline with MTBE. The Pennsylvania suit has been forwarded to the existing MTBE multidistrict litigation pending in the Southern District of New York. In September 2016, the State of Rhode Island also filed a lawsuit alleging that we and other major oil companies damaged the groundwater in Rhode Island by introducing thereto gasoline with MTBE. The suit filed in Rhode Island is proceeding in Federal court. In December 2017, the State of Maryland filed a lawsuit alleging that we and other major oil companies damaged the groundwater in Maryland by introducing thereto gasoline with MTBE. The suit filed in Maryland state court, was served on us in January 2018 and has been removed to Federal court by the defendants.

In September 2003, we received a directive from the New Jersey Department of Environmental Protection (NJDEP) to remediate contamination in the sediments of the Lower Passaic River. The NJDEP is also seeking natural resource damages. The directive, insofar as it affects us, relates to alleged releases from a petroleum bulk storage terminal in Newark, New Jersey we previously owned. We and over 70 companies entered into an Administrative Order on Consent with the Environmental Protection Agency (EPA) to study the same contamination; this work remains ongoing. We and other parties settled a cost recovery claim by the State of New Jersey and also agreed with EPA to fund remediation of a portion of the site. On March 4, 2016, the EPA issued a Record of Decision (ROD) in respect of the lower eight miles of the Lower Passaic River, selecting a remedy that includes bank-to-bank dredging at an estimated cost of $1.38 billion. The ROD does not address the upper nine miles of the Lower Passaic River or the Newark Bay, which may require additional remedial action. In addition, the Federal trustees for natural resources have begun a separate assessment of damages to natural resources in the Passaic River. Given that the EPA has not selected a remedy for the entirety of the Lower Passaic River or the Newark Bay, total remedial costs cannot be reliably estimated at this time. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us because our former terminal did not store or use contaminants which are of concern in the river sediments and could not have contributed contamination along the river’s length. Further, there are numerous other parties who we expect will bear the cost of remediation and damages.

In March 2014, we received an Administrative Order from EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York. The remedy includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap. EPA’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. Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected ship-building and repair facility adjacent to the Canal. We agreed to comply with the EPA Administrative Order and are currently contributing funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert.

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

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 the aforementioned proceedings is not expected to have a material adverse effect on our financial condition, results of operations or cash flows.

Segment Information

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Segment Information

12. Segment Information

We currently have two operating segments, Exploration and Production, and Midstream. All unallocated costs are reflected under Corporate, Interest and Other. The following table presents operating segment financial data:

	Exploration and Production			Midstream		Corporate, Interest and Other			Eliminations			Total
	(In millions)
For the Three Months Ended March 31, 2019
Sales and Other Operating Revenues - Third-parties	$	1,572		$	—	$	—		$	—		$	1,572
Intersegment Revenues		—			190		—			(190	)		—
Sales and Other Operating Revenues	$	1,572		$	190	$	—		$	(190	)	$	1,572

Net Income (Loss) attributable to Hess Corporation	$	109		$	37	$	(114	)	$	—		$	32
Depreciation, Depletion and Amortization		464			34		—			—			498
Provision (Benefit) for Income Taxes (a)		95			—		(1	)		—			94
Capital Expenditures		515			127		—			—			642

For the Three Months Ended March 31, 2018
Sales and Other Operating Revenues - Third-parties	$	1,346		$	—	$	—		$	—		$	1,346
Intersegment Revenues		—			167		—			(167	)		—
Sales and Other Operating Revenues	$	1,346		$	167	$	—		$	(167	)	$	1,346

Net Income (Loss) attributable to Hess Corporation	$	(25	)	$	28	$	(109	)	$	—		$	(106	)
Depreciation, Depletion and Amortization		385			31		1			—			417
Provision (Benefit) for Income Taxes (a)		95			9		(31	)		—			73
Capital Expenditures		354			37		—			—			391

(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, the provision for income taxes in the Midstream segment was presented before consolidating its operations with other U.S. activities of the Company and prior to evaluating realizability of net U.S. deferred taxes. An offsetting impact was presented in the E&P segment. If 2018 segment results were prepared on a basis consistent with 2019, Midstream segment net income attributable to Hess Corporation would have been $37 million and E&P segment net losses would have been $34 million in the first quarter of 2018.

Identifiable assets by operating segment were as follows:

	March 31,		December 31,
	2019		2018
	(In millions)
Exploration and Production	$	16,978	$	16,109
Midstream		3,280		3,285
Corporate, Interest and Other		1,458		2,039
Total	$	21,716	$	21,433

Financial Risk Management Activities

3 Months Ended

Mar. 31, 2019

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Financial Risk Management Activities

13. 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. 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 March 31, 2019, these forward contracts relate to the British Pound. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.

We present gross notional amounts of both long and short positions in the table below. These amounts include long and short positions that offset in closed positions and have not reached contractual maturity. Gross notional amounts do not quantify risk or represent assets or liabilities of the Corporation but are used in the calculation of cash settlements under the contracts.

The gross notional amounts of outstanding financial risk management derivative contracts related to West Texas Intermediate (WTI) instruments as of the dates shown below were as follows:

	March 31, 2019		December 31, 2018
Calendar year program	2019		2019
Instrument type	Puts		Puts
Effective date	Apr. 1, 2019		Jan. 1, 2019
End date	Dec. 31, 2019		Dec. 31, 2019
Crude oil volumes (millions of barrels)		26.1		34.7
Floor price	$	60	$	60

The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows:

	March 31, 2019		December 31, 2018
	(In millions)
Foreign exchange	$	43	$	16
Interest rate swaps	$	100	$	100

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)
March 31, 2019
Derivative Contracts Designated as Hedging Instruments:
Commodity - Other current assets	$	96	$	—
Interest rate - Other liabilities and deferred credits (noncurrent)		—		(1	)
Total derivative contracts designated as hedging instruments		96		(1	)
Gross fair value of derivative contracts		96		(1	)
Master netting arrangements		—		—
Net Fair Value of Derivative Contracts	$	96	$	(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 in the table above are based on Level 2 inputs.

Derivative contracts designated as hedging instruments:

Crude oil derivatives: Crude oil price hedging contracts increased Sales and other operating revenues by $15 million in the first quarter of 2019 and decreased Sales and other operating revenue by $30 million in the first quarter of 2018. At March 31, 2019, pre-tax deferred gains in Accumulated other comprehensive income (loss) related to outstanding crude oil price hedging contracts were $3 million, all of which will be reclassified into earnings during the remainder of 2019 as the originally hedged crude oil sales are recognized in earnings.

Interest rate swaps designated as fair value hedges: At March 31, 2019 and December 31, 2018, we had interest rate swaps with gross notional amounts totaling $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 the first quarter of 2019, the change in fair value of interest rate swaps was a decrease in the liability of $1 million (Q1 2018: increase in liability of $3 million) with a corresponding adjustment in the carrying value of the hedged fixed‑rate debt. In the first quarter of 2018, we paid $3 million, to terminate interest rate swaps with a gross notional amount of $350 million.

Derivative contracts not designated as hedging instruments:

Foreign exchange: Foreign exchange gains which are reported in Other, net in Revenues and non-operating income in the Statement of Consolidated Income were $5 million in the first quarter of 2019 (2018 Q1: $4 million). A component of foreign exchange gain is the result of foreign exchange derivative contracts that are not designated as hedges which amounted to a loss of less than $1 million in the first quarter of 2019 (2018 Q1: gain of $2 million).

Crude oil derivatives: In the first quarter of 2018, noncash adjustments to de-designated crude oil price hedging contracts decreased Sales and other operating revenues by $8 million.

Fair Value Measurement:

We have other short-term financial instruments, primarily cash equivalents, accounts receivable and accounts payable, for which the carrying value approximated fair value at March 31, 2019. At March 31, 2019, total long-term debt, which was substantially comprised of fixed-rate debt instruments, had a carrying value of $6,562 million and a fair value of $6,987 million based on Level 2 inputs.

Subsequent Events

3 Months Ended

Mar. 31, 2019

Subsequent Events [Abstract]

Subsequent Events

14. Subsequent Event

On April 18, 2019 the Corporation terminated its existing revolving credit facility maturing in January 2021 and entered into a new fully undrawn $3.5 billion revolving credit facility with a maturity date of May 15, 2023. This facility can be used for borrowings and letters of credit. Borrowings on the new facility will generally bear interest at 1.30% above the London Interbank Offered Rate (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 0.650 to 1.000, and customary events of default.

Basis of Presentation (Policies)	3 Months Ended
Basis of Presentation (Policies)	Mar. 31, 2019
Accounting Policies [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements: In June 2016, the FASB issued Accounting Standards Update (ASU) 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared to the current "incurred loss" model. We expect to adopt this ASU in the first quarter of 2020 when the standard becomes effective. We continue to evaluate this ASU but do not believe it will have a material impact on our Consolidated Financial Statements.

Basis of Presentation (Tables)

3 Months Ended

Mar. 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

Leases (Tables)

3 Months Ended

Mar. 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 March 31, 2019 were as follows:

	Operating Leases		Finance Leases
	(In millions)
Right-of-use assets — net (a)	$	713	$	332
Lease obligations:
Current	$	366	$	36
Long-term		436		250
Total lease obligations	$	802	$	286

(a)	Finance lease Right-of-use assets have a cost of $384 million and accumulated amortization of $52 million.

Schedule of Maturities of Lease Obligations

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

	Operating Leases			Finance Leases
	(In millions)
2019	$	308		$	48
2020		183			36
2021		71			36
2022		64			36
2023		64			36
Remaining years		197			248
Total lease payments		887			440
Less: Imputed interest		(85	)		(154	)
Total lease obligations	$	802		$	286

Summary of Information Relates to Operating and Finance Leases Recorded

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

	Operating Leases	Finance Leases
Weighted average remaining lease term	4.7 years	13.5 years
Range of remaining lease terms	0.1 - 9.3 years	0.2 - 14.5 years
Weighted average discount rate	4.3%	7.8%

Schedule of Components of Lease Cost

The components of lease costs in the first quarter of 2019 were as follows (in millions):

Operating lease cost	$	103
Finance lease cost:
Amortization of leased assets		13
Interest on lease obligations		6
Short-term lease cost (a)		32
Variable lease cost (b)		19
Sublease income (c)		(3	)
Total lease cost	$	170

(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.

Supplemental Cash Flow Information Related to Leases

Supplemental cash flow information related to leases for the first quarter of 2019 was as follows:

	Operating Leases		Finance Leases
	(In millions)
Cash paid for amounts included in the measurement of lease obligations:
Operating cash flows	$	106	$	6
Financing cash flows		—		23
Noncash transactions:
Leased assets recognized for new lease obligations incurred	3			—

Revenue (Tables)

3 Months Ended

Mar. 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			Denmark		Libya		Malaysia & JDA		E&P Total
Three Months Ended March 31, 2019
Sales of our net production volumes:
Crude oil revenue	$	682		$	16	$	91	$	21	$	810		$	—	$	—		$	810
Natural gas liquids revenue		68			—		—		—		68			—		—			68
Natural gas revenue		42			3		6		180		231			—		—			231
Sales of purchased oil and gas		426			—		22		—		448			—		—			448
Intercompany revenue		—			—		—		—		—			190		(190	)		—
Total revenues from contracts with customers		1,218			19		119		201		1,557			190		(190	)		1,557
Other operating revenues (a)		15			—		—		—		15			—		—			15
Total sales and other operating revenues	$	1,233		$	19	$	119	$	201	$	1,572		$	190	$	(190	)	$	1,572

Three Months Ended March 31, 2018
Sales of our net production volumes:
Crude oil revenue	$	593		$	33	$	99	$	43	$	768		$	—	$	—		$	768
Natural gas liquids revenue		71			—		—		—		71			—		—			71
Natural gas revenue		39			3		8		128		178			—		—			178
Sales of purchased oil and gas		325			—		24		14		363			—		—			363
Intercompany revenue		—			—		—		—		—			167		(167	)		—
Total revenues from contracts with customers		1,028			36		131		185		1,380			167		(167	)		1,380
Other operating revenues (a)		(34	)		—		—		—		(34	)		—		—			(34	)
Total sales and other operating revenues	$	994		$	36	$	131	$	185	$	1,346		$	167	$	(167	)	$	1,346

(a)	Includes gains (losses) on commodity derivatives.

Inventories (Tables)

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Inventories

Inventories consisted of the following:

	March 31,		December 31,
	2019		2018
	(In millions)
Crude oil and natural gas liquids	$	96	$	74
Materials and supplies		178		171
Total Inventories	$	274	$	245

Capitalized Exploratory Well Costs (Tables)

3 Months Ended

Mar. 31, 2019

Capitalized Exploratory Well Costs [Abstract]

Net Changes in Capitalized Exploratory Well Costs

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the three months ended March 31, 2019 (in millions):

Balance at January 1, 2019	$	418
Additions to capitalized exploratory well costs pending the determination of proved reserves		48
Balance at March 31, 2019	$	466

Retirement Plans (Tables)

3 Months Ended

Mar. 31, 2019

Compensation And Retirement Disclosure [Abstract]

Components of Net Periodic Pension Cost

Components of net periodic pension cost consisted of the following:

	Three Months Ended
	March 31,
	2019			2018
	(In millions)
Service cost	$	10		$	14
Interest cost (a)		24			23
Expected return on plan assets (a)		(45	)		(49	)
Amortization of unrecognized net actuarial losses (a)		11			12
Curtailment gains (a)		—			(2	)
Pension (income) expense (a)	$	—		$	(2	)

(a) Net non-service pension cost included in Other, net in the Statement of Consolidated Income in the first quarter of 2019 was income of $10 million (2018: $16 million of income).

Weighted Average Common Shares (Tables)

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Net Income (Loss) and Weighted Average Number of Common Shares Used in the Computation of Basic and Diluted Earnings Per Share

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

	Three Months Ended
	March 31,
	2019		2018
	(In millions)
Net income (loss) attributable to Hess Corporation Common Stockholders:

Net income (loss)	$	75	$	(65	)
Less: Net income (loss) attributable to noncontrolling interests		43		41
Less: Preferred stock dividends		4		11
Net income (loss) attributable to Hess Corporation Common Stockholders	$	28	$	(117	)

Weighted average number of common shares outstanding:

Basic		297.4		309.5
Effect of dilutive securities
Restricted common stock		1.2		—
Stock options		0.2		—
Performance share units		0.9		—
Diluted		299.7		309.5

Summary of Antidilutive Shares Excluded from Computation of Diluted Shares

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

	Three Months Ended
	March 31,
	2019		2018
Restricted common stock		57,252		2,922,316
Stock options		3,394,418		5,807,579
Performance share units		65,661		623,088
Common shares from conversion of preferred stocks		3,930,663		12,584,974

Segment Information (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Financial Data and Identifiable Assets by Operating Segment

	Exploration and Production			Midstream		Corporate, Interest and Other			Eliminations			Total
	(In millions)
For the Three Months Ended March 31, 2019
Sales and Other Operating Revenues - Third-parties	$	1,572		$	—	$	—		$	—		$	1,572
Intersegment Revenues		—			190		—			(190	)		—
Sales and Other Operating Revenues	$	1,572		$	190	$	—		$	(190	)	$	1,572

Net Income (Loss) attributable to Hess Corporation	$	109		$	37	$	(114	)	$	—		$	32
Depreciation, Depletion and Amortization		464			34		—			—			498
Provision (Benefit) for Income Taxes (a)		95			—		(1	)		—			94
Capital Expenditures		515			127		—			—			642

For the Three Months Ended March 31, 2018
Sales and Other Operating Revenues - Third-parties	$	1,346		$	—	$	—		$	—		$	1,346
Intersegment Revenues		—			167		—			(167	)		—
Sales and Other Operating Revenues	$	1,346		$	167	$	—		$	(167	)	$	1,346

Net Income (Loss) attributable to Hess Corporation	$	(25	)	$	28	$	(109	)	$	—		$	(106	)
Depreciation, Depletion and Amortization		385			31		1			—			417
Provision (Benefit) for Income Taxes (a)		95			9		(31	)		—			73
Capital Expenditures		354			37		—			—			391

(a)

Identifiable assets by operating segment were as follows:

	March 31,		December 31,
	2019		2018
	(In millions)
Exploration and Production	$	16,978	$	16,109
Midstream		3,280		3,285
Corporate, Interest and Other		1,458		2,039
Total	$	21,716	$	21,433

Financial Risk Management Activities (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments Gain Loss [Line Items]

Gross and Net Fair Values of Financial Risk Management Derivative Instruments

The table below reflects the gross and net fair values of risk management derivative instruments and their respective financial statement caption in the Consolidated Balance Sheet:

	Assets		Liabilities
	(In millions)
March 31, 2019
Derivative Contracts Designated as Hedging Instruments:
Commodity - Other current assets	$	96	$	—
Interest rate - Other liabilities and deferred credits (noncurrent)		—		(1	)
Total derivative contracts designated as hedging instruments		96		(1	)
Gross fair value of derivative contracts		96		(1	)
Master netting arrangements		—		—
Net Fair Value of Derivative Contracts	$	96	$	(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	)

Derivative Instruments Gain Loss [Line Items]

Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts

The gross notional amounts of outstanding financial risk management derivative contracts related to West Texas Intermediate (WTI) instruments as of the dates shown below were as follows:

	March 31, 2019		December 31, 2018
Calendar year program	2019		2019
Instrument type	Puts		Puts
Effective date	Apr. 1, 2019		Jan. 1, 2019
End date	Dec. 31, 2019		Dec. 31, 2019
Crude oil volumes (millions of barrels)		26.1		34.7
Floor price	$	60	$	60

Excluding West Texas Intermediate (WTI)

Derivative Instruments Gain Loss [Line Items]

Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts

The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows:

	March 31, 2019		December 31, 2018
	(In millions)
Foreign exchange	$	43	$	16
Interest rate swaps	$	100	$	100

- 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

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
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Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5580258-113959

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41620-113959

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5579245-113959

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
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-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41638-113959

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
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-Name Accounting Standards Codification
-Topic 815
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-Section 50
-Paragraph 8
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Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5579240-113959

+ Details

Basis of Presentation - Additional Information (Detail) - USD ($)	Jan. 31, 2019	Dec. 31, 2017
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Cumulative effect of retained earnings		$ 0
ASC 842
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Cumulative effect of retained earnings	$ 0

Basis of Presentation - Schedule of Impact of adoption on Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Assets
Property, plant and equipment — net	$ 15,898		$ 16,083
Operating lease right-of-use assets — net	713		0
Finance lease right-of-use assets — net	332		0
Liabilities
Accrued liabilities	1,369		1,560
Current maturities of long-term debt	12		67
Current portion of operating and finance lease obligations	402		0
Long-term debt	6,550		6,605
Long-term operating lease obligations	436		0
Long-term finance lease obligations	250		0
Other liabilities and deferred credits	$ 491		$ 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 - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease right-of-use assets — net	$ 713	$ 0
Operating Leases, Lease obligations:
Operating Leases, Lease Liabilities, Current	366
Long-term operating lease obligations	436	0
Operating Leases, Total lease obligations	802
Finance lease right-of-use assets — net	332	0
Financing Leases, Lease obligations:
Financing Leases, Lease liabilities, Current	36
Financing Leases, Lease liabilities, Long-term	250	$ 0
Financing Leases, Total lease obligations	$ 286

Leases - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Parenthetical) (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Leases [Abstract]
Finance lease, right-of-use assets, amortization cost	$ 384
Finance lease, right-of-use assets, accumulated amortization	$ 52

Leases - Additional Information (Detail) - USD ($)	3 Months Ended	12 Months Ended
Leases - Additional Information (Detail) - USD ($)	Mar. 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%
Carrying value of finance lease asset	$ 332,000,000	$ 0
Carrying value of finance lease obligation	$ 286,000,000
Lease payments as 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%
Gain or loss on sale of transaction		$ 0
Finance lease term	14 years 6 months
Carrying value of finance lease asset	$ 256,000,000
Carrying value of finance lease obligation	266,000,000
Floating, Storage and Offloading Vessel \| Additional Finance Lease Obligation
Leases [Line Items]
Finance lease obligation to be settlement in future	$ 20,000,000

Leases - Schedule of Maturities of Lease Obligations (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Leases [Abstract]
Operating Leases, 2019	$ 308
Operating Leases, 2020	183
Operating Leases, 2021	71
Operating Leases, 2022	64
Operating Leases, 2023	64
Operating Leases, Remaining years	197
Total lease payments	887
Less: Imputed interest	(85)
Total lease obligations	802
Financing Leases, 2019	48
Financing Leases, 2020	36
Financing Leases, 2021	36
Financing Leases, 2022	36
Financing Leases, 2023	36
Financing Leases, Remaining years	248
Total lease payments	440
Less: Imputed interest	(154)
Total lease obligations	$ 286

Leases - Summary of Information Relates to Operating and Finance Leases Recorded (Detail)	3 Months Ended
	Mar. 31, 2019
Leases [Line Items]
Operating leases, Weighted average remaining lease term	4 years 8 months 12 days
Operating leases, Weighted average discount rate	4.30%
Finance leases, Weighted average remaining lease term	13 years 6 months
Finance leases, Weighted average discount rate	7.80%
Minimum
Leases [Line Items]
Operating leases, Range of remaining lease terms	1 month 6 days
Finance leases, Range of remaining lease terms	2 months 12 days
Maximum
Leases [Line Items]
Operating leases, Range of remaining lease terms	9 years 3 months 18 days
Finance leases, Range of remaining lease terms	14 years 6 months

Leases - Components of Lease Costs (Detail) $ in Millions	3 Months Ended
Leases - Components of Lease Costs (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Leases [Abstract]
Operating lease cost	$ 103
Finance lease cost:
Amortization of leased assets	13
Interest on lease obligations	6
Short-term lease cost	32
Variable lease cost	19
Sublease income	(3)
Total lease cost	$ 170

Leases - Supplemental Cash Flow Information Related to Leases (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Cash paid for amounts included in the measurement of lease obligations:
Operating Leases, Operating cash flows	$ 106
Operating Leases, Financing cash flows	0
Finance Leases, Operating cash flows	6
Finance Leases, Financing cash flows	23	$ 0
Noncash transactions:
Operating Leases, Leased assets recognized for new lease obligations incurred	3
Finance Leases, Leased assets recognized for new lease obligations incurred	$ 0

Preferred Stock Conversion - Additional Information (Detail) - shares shares in Millions		3 Months Ended	12 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Class Of Stock [Line Items]
Series A, cumulative mandatory convertible preferred stock - dividend rate		8.00%	8.00%
Series A Mandatory Convertible Preferred Stock
Class Of Stock [Line Items]
Common stock issuance following preferred stock conversion	12.5
Series A, cumulative mandatory convertible preferred stock - dividend rate	8.00%
Number of common shares received from capped call upon conversion of preferred stocks	0.9
Net number of common shares issued upon conversion of preferred stocks	11.6
Convertible preferred stock conversion in to common stock converted shares		21.822

- Definition

Specific terms relevant to convertibility. Includes class of preferred stock and number of shares convertible into, exercise (or conversion) price or rates, dates relevant to conversion timing and events relevant to conversion. Describe also any beneficial conversion features. where convertible preferred stock with a nondetachable conversion feature is in-the-money at commitment date. For contingently convertible preferred stock, discuss the circumstances of the contingency, including the events or changes in circumstance that would cause the contingency to be met and any of the significant features necessary to understand the conversion rights and the timing of those rights. Include also an events or changes in circumstance, if any, that could adjust or change the contingency, conversion price, or number of shares, including significant terms of those changes.

+ References + Details

Revenue - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Exploration and Production
Disaggregation Of Revenue [Line Items]
Credit losses on receivables with customers	$ 0	$ 0

Inventories - Inventories (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 96	$ 74
Materials and supplies	178	171
Total Inventories	$ 274	$ 245

Capitalized Exploratory Well Costs - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 418
Additions to capitalized exploratory well costs pending the determination of proved reserves	48
Ending balance	$ 466

Capitalized Exploratory Well Costs - Additional Information (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Capitalized Exploratory Well Costs [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 309
Liza-4, Pacora-1 Payara-1, Payara-2, Ranger-1 and Snoek-1 Wells on the Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	45.00%
Project interest percentage	30.00%
Northern Portion of Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	40.00%
Project interest percentage	28.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	10.00%
Project interest percentage	50.00%
North Malay Basin, offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	5.00%
Project interest percentage	50.00%

Hess Infrastructure Partners LP - Additional Information (Detail) - USD ($) $ in Millions			3 Months Ended
	Mar. 22, 2019	Mar. 01, 2019	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Variable Interest Entity [Line Items]
Cash and cash equivalents			$ 2,300	$ 2,694	$ 3,726	$ 4,847
Property, plant and equipment, net			$ 15,898	16,083
Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Ownership percentage in Hess Infrastructure Partners LP (HIP) by Hess Corporation			50.00%
Water disposal management business, cash paid		$ 225
Cash consideration	$ 90
Contingent payments subject to certain future performance	$ 10
Hess Infrastructure Partners LP (HIP) \| Additional Paid-in-Capital
Variable Interest Entity [Line Items]
Sale of water management business, after-tax gain offset to noncontrolling interests		$ 78
Hess Infrastructure Partners LP (HIP) \| Midstream Segment
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage			80.00%
Variable Interest Entity, Primary Beneficiary \| Hess Infrastructure Partners LP (HIP)
Variable Interest Entity [Line Items]
Ownership percentage in Hess Infrastructure Partners LP (HIP) by Hess Corporation			50.00%
Cash and cash equivalents			$ 6	109
Property, plant and equipment, net			2,829	2,664
HIP's liabilities on a nonrecourse to Hess Corporation			$ 1,273	$ 1,105
Variable Interest Entity, Primary Beneficiary \| Hess Midstream Partners LP (HIP) \| Midstream Segment
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage			20.00%

Retirement Plans - Components of Net Periodic Pension Cost (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Compensation And Retirement Disclosure [Abstract]
Service cost	$ 10	$ 14
Interest cost	24	23
Expected return on plan assets	(45)	(49)
Amortization of unrecognized net actuarial losses	11	12
Curtailment gains	0	(2)
Pension (income) expense	$ 0	$ (2)

Retirement Plans - Components of Net Periodic Pension Cost (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Compensation And Retirement Disclosure [Abstract]
Net non-service pension income included in Other, net	$ 10	$ 16

Retirement Plans - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Compensation And Retirement Disclosure [Abstract]
Corporation's estimated contribution for funded pension plans in 2019	$ 40
Corporation's contribution for funded pension plan during the year to date	$ 10

Debt - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument Redemption [Line Items]
Terminated interest rate swaps	terminated interest rate swaps with a notional amount of $350 million
Amount of terminated interest rate swaps		$ 350
Loss on debt extinguishment	$ 0	27
Revolving Credit Facility
Debt Instrument Redemption [Line Items]
Borrowing from revolving credit line	$ 199
Other Notes
Debt Instrument Redemption [Line Items]
Carrying value of purchased debt			$ 38
8.125% Notes Due 2019
Debt Instrument Redemption [Line Items]
Debt instrument redemption amount		415
Debt instrument redemption of principal amount		$ 350
Debt instrument interest rate		8.125%
Debt instrument maturity year		2019
Carrying value of purchased debt			$ 349

Weighted Average Common Shares - Basic and Diluted Earnings Per Share (Detail) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net Income (Loss)	$ 75	$ (65)
Less: Net income (loss) attributable to noncontrolling interests	43	41
Less: Preferred stock dividends	4	11
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ 28	$ (117)
Weighted average number of common shares outstanding:
Basic	297.4	309.5
Diluted	299.7	309.5
Restricted Common Stock
Weighted average number of common shares outstanding:
Effect of dilutive securities	1.2	0.0
Stock Options
Weighted average number of common shares outstanding:
Effect of dilutive securities	0.2	0.0
Performance Share Units
Weighted average number of common shares outstanding:
Effect of dilutive securities	0.9	0.0

Weighted Average Common Shares - Antidilutive Shares Excluded from Computation of Diluted Shares (Detail) - shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Restricted Common Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	57,252	2,922,316
Stock Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	3,394,418	5,807,579
Performance Share Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	65,661	623,088
Common Shares from Conversion of Preferred Stocks
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	3,930,663	12,584,974

Weighted Average Common Shares - Additional Information (Detail) - shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Equity [Abstract]
Shares granted, restricted stock	941,082	1,081,923
Shares granted, performance share units	234,866	278,003
Shares granted, stock options	526,968	683,167

Guarantees and Contingencies - Additional Information (Detail) $ in Millions		1 Months Ended	3 Months Ended
	Mar. 04, 2016 USD ($)	Mar. 31, 2014 USD ($)	Mar. 31, 2019 USD ($) 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	$ 1,380.0
Gowanus Canal Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost		$ 506.0
Ector Drum, Inc. Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost			$ 3.5

Segment Information - Additional Information (Detail)	3 Months Ended
Segment Information - Additional Information (Detail)	Mar. 31, 2019 Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	2

Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	$ 1,572	$ 1,346
Intersegment revenues	0	0
Total sales and other operating revenues	1,572	1,346
Net Income (Loss) attributable to Hess Corporation	32	(106)
Depreciation, depletion and amortization	498	417
Provision (benefit) for income taxes	94	73
Capital Expenditures	642	391
Identifiable assets	21,716		$ 21,433
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0
Intersegment revenues	(190)	(167)
Total sales and other operating revenues	(190)	(167)
Net Income (Loss) attributable to Hess Corporation	0	0
Depreciation, depletion and amortization	0	0
Provision (benefit) for income taxes	0	0
Capital Expenditures	0	0
Exploration and Production \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	1,572	1,346
Intersegment revenues	0	0
Total sales and other operating revenues	1,572	1,346
Net Income (Loss) attributable to Hess Corporation	109	(25)
Depreciation, depletion and amortization	464	385
Provision (benefit) for income taxes	95	95
Capital Expenditures	515	354
Identifiable assets	16,978		16,109
Midstream \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0
Intersegment revenues	190	167
Total sales and other operating revenues	190	167
Net Income (Loss) attributable to Hess Corporation	37	28
Depreciation, depletion and amortization	34	31
Provision (benefit) for income taxes	0	9
Capital Expenditures	127	37
Identifiable assets	3,280		3,285
Corporate, Interest and Other \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0
Intersegment revenues	0	0
Total sales and other operating revenues	0	0
Net Income (Loss) attributable to Hess Corporation	(114)	(109)
Depreciation, depletion and amortization	0	1
Provision (benefit) for income taxes	(1)	(31)
Capital Expenditures	0	$ 0
Identifiable assets	$ 1,458		$ 2,039

Segment Information - Financial Data by Operating Segment (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Net income (losses)	$ 32	$ (106)
Midstream Segment \| Operating Segments
Segment Reporting Information [Line Items]
Net income (losses)	37	28
Midstream Segment \| Operating Segments \| Pro Forma
Segment Reporting Information [Line Items]
Net income (losses)		37
Exploration and Production \| Operating Segments
Segment Reporting Information [Line Items]
Net income (losses)	$ 109	(25)
Exploration and Production \| Operating Segments \| Pro Forma
Segment Reporting Information [Line Items]
Net income (losses)		$ (34)

- Definition

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

+ References + Details

Financial Risk Management Activities - Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts (Detail) - WTI - 2019	3 Months Ended	12 Months Ended
	Mar. 31, 2019 MMBbls $ / bbl	Dec. 31, 2018 MMBbls $ / bbl
Derivative [Line Items]
Calendar year program	2019	2019
Instrument type	Puts
Effective date	Apr. 01, 2019	Jan. 01, 2019
End date	Dec. 31, 2019	Dec. 31, 2019
Crude oil volumes (millions of barrels) \| MMBbls	26.1	34.7
Floor price \| $ / bbl	60	60

Financial Risk Management Activities - Gross Notional Amounts of Derivative Contracts Outstanding Excluding Commodity Contracts (Detail) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Foreign Exchange
Derivative [Line Items]
Outstanding gross notional amount	$ 43,000,000	$ 16,000,000
Interest Rate Swaps \| Designated as Fair Value Hedges
Derivative [Line Items]
Outstanding gross notional amount	$ 100,000,000	$ 100,000,000

Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 96	$ 484
Assets – Master netting arrangements	0	0
Assets - Net Fair Value of Derivative Contracts	96	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	96	484
Liabilities - Gross fair value of derivative contracts	(1)	(2)
Derivative Contracts Designated as Hedging Instruments \| Commodity \| Other Current Assets
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	96	484
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments \| Commodity \| Other Liabilities and Deferred Credits
Derivatives Fair Value [Line Items]
Liabilities - Gross fair value of derivative contracts	(1)	(2)
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	$ 0

Financial Risk Management Activities - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Derivative Instruments Gain Loss [Line Items]
Amount of terminated interest rate swaps		$ 350,000,000
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 - (increase) decrease in derivative liability	1,000,000	(3,000,000)
Payment to terminate interest rate swaps		3,000,000
Foreign Exchange
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	43,000,000		$ 16,000,000
Foreign exchange gains reported in Other, net in Revenues and Non-Operating Income in the Statement of Consolidated Income	5,000,000	4,000,000
Gain (Loss) on foreign exchange contracts not designated as hedging instruments		2,000,000
Foreign Exchange \| Maximum
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on foreign exchange contracts not designated as hedging instruments	(1,000,000)
Derivative Contracts Designated as Hedging Instruments \| Crude Oil
Derivative Instruments Gain Loss [Line Items]
Crude oil price hedging contracts increased (decreased) Sales and other operating revenues by this amount, pre-tax	(15,000,000)	(30,000,000)
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings during the remainder of 2019	$ 3,000,000
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		$ (8,000,000)

Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Carrying value
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt	$ 6,562
Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt fair value	$ 6,987

Subsequent Events - Additional Information (Detail) - Revolving Credit Facility - Subsequent Event $ in Billions	Apr. 18, 2019 USD ($)
Subsequent Event [Line Items]
Debt Instrument, undrawn borrowing capacity, amount	$ 3.5
Debt instrument maturity year	May 15, 2023
Debt instrument covenant, description	1.30%
Debt instrument covenant, ratio	0.65
Revolving credit facility expiration date	Jan. 31, 2021