Hess (HES) 10-Q 7 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2019shares
Cover [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Trading Symbol	HES
Security Exchange Name	NYSE
Entity Registrant Name	HESS CORPORATION
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
Title of 12(b) Security	Common Stock
Entity Common Stock, Shares Outstanding	304,706,235
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
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 Quarterly Report	true
Document Transition Report	false

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 1,863	$ 2,694
Accounts receivable:
From contracts with customers	889	771
Joint venture and other	233	230
Inventories	289	245
Other current assets	124	519
Total current assets	3,398	4,459
Property, plant and equipment:
Total — at cost	34,955	33,222
Less: Reserves for depreciation, depletion, amortization and lease impairment	18,506	17,139
Property, plant and equipment — net	16,449	16,083
Operating lease right-of-use assets — net	527	0
Finance lease right-of-use assets — net	308	0
Goodwill	360	360
Deferred income taxes	18	21
Other assets	571	510
Total Assets	21,631	21,433
Current Liabilities:
Accounts payable	396	495
Accrued liabilities	1,570	1,560
Taxes payable	104	81
Current maturities of long-term debt	15	67
Current portion of operating and finance lease obligations	259	0
Total current liabilities	2,344	2,203
Long-term debt	6,526	6,605
Long-term operating lease obligations	372	0
Long-term finance lease obligations	242	0
Deferred income taxes	411	421
Asset retirement obligations	850	741
Other liabilities and deferred credits	709	575
Total Liabilities	11,454	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 - 304,706,235 shares (2018: 291,434,534)	305	291
Capital in excess of par value	5,543	5,386
Retained earnings	3,836	4,257
Accumulated other comprehensive income (loss)	(776)	(306)
Total Hess Corporation stockholders’ equity	8,908	9,629
Noncontrolling interests	1,269	1,259
Total equity	10,177	10,888
Total Liabilities and Equity	$ 21,631	$ 21,433

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - $ / shares	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 1	$ 1
Preferred stock, shares authorized	20,000,000	20,000,000
Preferred stock, shares issued	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	$ 1
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	304,706,235	291,434,534

Statement of Consolidated Incom

Statement of Consolidated Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues and Non-Operating Income
Sales and other operating revenues	$ 1,580	$ 1,793	$ 4,812	$ 4,673
Gains on asset sales, net	0	14	22	32
Other, net	(65)	21	(23)	79
Total revenues and non-operating income	1,515	1,828	4,811	4,784
Costs and Expenses
Marketing, including purchased oil and gas	423	491	1,308	1,299
Operating costs and expenses	321	266	872	842
Production and severance taxes	47	47	132	128
Exploration expenses, including dry holes and lease impairment	50	169	127	271
General and administrative expenses	90	143	266	382
Interest expense	90	99	285	300
Loss on debt extinguishment	0	0	0	53
Depreciation, depletion and amortization	544	489	1,536	1,350
Total costs and expenses	1,565	1,704	4,526	4,625
Income (Loss) Before Income Taxes	(50)	124	285	159
Provision (benefit) for income taxes	116	121	342	308
Net Income (Loss)	(166)	3	(57)	(149)
Less: Net income (loss) attributable to noncontrolling interests	46	45	129	129
Net Income (Loss) Attributable to Hess Corporation	(212)	(42)	(186)	(278)
Less: Preferred stock dividends	0	11	4	34
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (212)	$ (53)	$ (190)	$ (312)
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$ (0.70)	$ (0.18)	$ (0.63)	$ (1.04)
Diluted	$ (0.70)	$ (0.18)	$ (0.63)	$ (1.04)
Weighted Average Number of Common Shares Outstanding:
Basic	302.5	294.3	300.7	300.4
Diluted	302.5	294.3	300.7	300.4
Common Stock Dividends Per Share	$ 0.25	$ 0.25	$ 0.75	$ 0.75

Statement of Consolidated Compr

Statement of Consolidated Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement Of Income And Comprehensive Income [Abstract]
Net Income (Loss)	$ (166)	$ 3	$ (57)	$ (149)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	(2)	49	(3)	129
Income taxes on effect of hedge (gains) losses reclassified to income	0	0	0	0
Net effect of hedge (gains) losses reclassified to income	(2)	49	(3)	129
Change in fair value of cash flow hedges	12	(49)	(334)	(84)
Income taxes on change in fair value of cash flow hedges	0	12	0	12
Net change in fair value of cash flow hedges	12	(37)	(334)	(72)
Change in derivatives designated as cash flow hedges, after taxes	10	12	(337)	57
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	(239)	0	(257)	130
Income taxes on actuarial changes in plan liabilities	0	0	0	(31)
(Increase) reduction in unrecognized actuarial losses, net	(239)	0	(257)	99
Amortization of net actuarial losses	101	8	124	29
Income taxes on amortization of net actuarial losses	0	0	0	0
Net effect of amortization of net actuarial losses	101	8	124	29
Change in pension and other postretirement plans, after taxes	(138)	8	(133)	128
Other Comprehensive Income (Loss)	(128)	20	(470)	185
Comprehensive Income (Loss)	(294)	23	(527)	36
Less: Comprehensive income (loss) attributable to noncontrolling interests	46	45	129	129
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (340)	$ (22)	$ (656)	$ (93)

Statement of Consolidated Cash

Statement of Consolidated Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash Flows From Operating Activities
Net income (loss)	$ (57)	$ (149)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Gains on asset sales, net	(22)	(32)
Depreciation, depletion and amortization	1,536	1,350
Exploratory dry hole costs	10	132
Exploration lease and other impairment	14	28
Pension settlement loss	88	0
Stock compensation expense	66	53
Noncash (gains) losses on commodity derivatives, net	87	134
Provision (benefit) for deferred income taxes and other tax accruals	(5)	(28)
Loss on debt extinguishment	0	53
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(129)	(247)
(Increase) decrease in inventories	(44)	(35)
Increase (decrease) in accounts payable and accrued liabilities	(127)	(140)
Increase (decrease) in taxes payable	22	9
Changes in other operating assets and liabilities	(83)	(70)
Net cash provided by (used in) operating activities	1,356	1,058
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(1,720)	(1,265)
Additions to property, plant and equipment - Midstream	(284)	(168)
Payments for Midstream equity investments	(33)	(67)
Proceeds from asset sales, net of cash sold	22	607
Other, net	(3)	(8)
Net cash provided by (used in) investing activities	(2,018)	(901)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	176	0
Debt with maturities of greater than 90 days – Repayments	(8)	(610)
Payments on finance lease obligations	(47)	0
Common stock acquired and retired	(25)	(1,120)
Cash dividends paid	(241)	(262)
Noncontrolling interests, net	(41)	(36)
Other, net	17	28
Net cash provided by (used in) financing activities	(169)	(2,000)
Net Increase (Decrease) in Cash and Cash Equivalents	(831)	(1,843)
Cash and Cash Equivalents at Beginning of Year	2,694	4,847
Cash and Cash Equivalents at End of Period	$ 1,863	$ 3,004

Statement of Consolidated Equit

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)	(149)	0	0	0	(278)	0	(278)	129
Other comprehensive income (loss)	185	0	0	0	0	185	185	0
Share-based compensation	84	0	1	83	0	0	84	0
Dividends on preferred stock	(34)	0	0	0	(34)	0	(34)	0
Dividends on common stock	(228)	0	0	0	(228)	0	(228)	0
Common stock acquired and retired	(1,130)	0	(20)	(462)	(648)	0	(1,130)	0
Noncontrolling interests, net	(36)	0	0	0	0	0	0	(36)
Balance at Sep. 30, 2018	11,046	1	296	5,445	4,410	(502)	9,650	1,396
Balance at Jun. 30, 2018	11,336	1	300	5,501	4,692	(522)	9,972	1,364
Net income (loss)	3	0	0	0	(42)	0	(42)	45
Other comprehensive income (loss)	20	0	0	0	0	20	20	0
Share-based compensation	36	0	0	36	0	0	36	0
Dividends on preferred stock	(11)	0	0	0	(11)	0	(11)	0
Dividends on common stock	(75)	0	0	0	(75)	0	(75)	0
Common stock acquired and retired	(250)	0	(4)	(92)	(154)	0	(250)	0
Noncontrolling interests, net	(13)	0	0	0	0	0	0	(13)
Balance at Sep. 30, 2018	11,046	1	296	5,445	4,410	(502)	9,650	1,396
Balance at Dec. 31, 2018	10,888	1	291	5,386	4,257	(306)	9,629	1,259
Net income (loss)	(57)	0	0	0	(186)	0	(186)	129
Other comprehensive income (loss)	(470)	0	0	0	0	(470)	(470)	0
Preferred stock conversion	0	(1)	12	(11)	0	0	0	0
Share-based compensation	92	0	2	90	0	0	92	0
Dividends on preferred stock	(4)	0	0	0	(4)	0	(4)	0
Dividends on common stock	(231)	0	0	0	(231)	0	(231)	0
Sale of water business to Hess Infrastructure Partners	0	0	0	78	0	0	78	(78)
Noncontrolling interests, net	(41)	0	0	0	0	0	0	(41)
Balance at Sep. 30, 2019	10,177	0	305	5,543	3,836	(776)	8,908	1,269
Balance at Jun. 30, 2019	10,531	0	304	5,513	4,125	(648)	9,294	1,237
Net income (loss)	(166)	0	0	0	(212)	0	(212)	46
Other comprehensive income (loss)	(128)	0	0	0	0	(128)	(128)	0
Share-based compensation	31	0	1	30	0	0	31	0
Dividends on common stock	(77)	0	0	0	(77)	0	(77)	0
Noncontrolling interests, net	(14)	0	0	0	0	0	0	(14)
Balance at Sep. 30, 2019	$ 10,177	$ 0	$ 305	$ 5,543	$ 3,836	$ (776)	$ 8,908	$ 1,269

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 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 September 30, 2019 and December 31, 2018, the consolidated results of operations for the three and nine months ended September 30, 2019 and 2018, and consolidated cash flows for the nine months ended September 30, 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 Extractive Activities – Oil and Gas The adoption of ASC 842 did not have an impact on our Statement of Consolidated Income Statement of Consolidated Cash Flows 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 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 with 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

Leases	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Leases	2. Le ases 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. 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 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 Operating Leases Finance Leases (In millions) Right-of-use assets - net (a) $ 527 $ 308 Lease obligations: Current $ 243 $ 16 Long-term 372 242 Total lease obligations $ 615 $ 258 (a) Finance lease ROU assets have a cost of $381 million and accumulated amortization of $73 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 September 30, 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 the third quarter of 2018, we entered into a sale and lease-back arrangement for a floating storage and offloading vessel 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 remaining lease term utilized in the lease obligation is 14.0 years. Maturities of lease obligations at September 30, 2019 were as follows: Operating Leases Finance Leases (In millions) 2019 $ 104 $ 9 2020 186 36 2021 70 36 2022 63 36 2023 63 36 Remaining years 199 248 Total lease payments 685 401 Less: Imputed interest (70 ) (143 ) Total lease obligations $ 615 $ 258 The following information relates to the Operating and Finance leases recorded at September 30, 2019: Operating Leases Finance Leases Weighted average remaining lease term 5.1 years 14.0 years Range of remaining lease terms 0.2 - 16.3 years 14.0 years Weighted average discount rate 4.3% 7.9% The components of lease costs were as follows: Three Months Ended Nine Months Ended September 30, 2019 (In millions) Operating lease cost $ 102 $ 312 Finance lease cost: Amortization of leased assets 10 34 Interest on lease obligations 5 16 Short-term lease cost (a) 45 116 Variable lease cost (b) 22 62 Sublease income (c) (3 ) (9 ) Total lease cost $ 181 $ 531 (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 nine months ended September 30, 2019 was as follows: Operating Leases Finance Leases (In millions) Cash paid for amounts included in the measurement of lease obligations (a): Operating cash flows $ 314 $ 16 Financing cash flows — 52 Noncash transactions: Leased assets recognized for new lease obligations incurred 10 — (a) Amounts represent gross lease payments before any recovery from partners.

Preferred Stock Conversion

Preferred Stock Conversion	9 Months Ended
	Sep. 30, 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 Corporation entered into capped call transactions to reduce the potential dilution to the Corporation’s common stock upon conversion of the Preferred Stock, subject to a cap. The Corporation 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 Corporation upon conversion of the Preferred Stock was approximately 11.6 million shares.

Revenue

Revenue	9 Months Ended
	Sep. 30, 2019
Revenue From Contract With Customer [Abstract]
Revenue	4. Revenue Revenue from contracts with customers on a disaggregated basis was as follows: Exploration and Production Midstream Eliminations Total United States Denmark Libya Malaysia & JDA E&P Total (In millions) Three Months Ended September 30, 2019 Sales of our net production volumes: Crude oil revenue $ 749 $ 31 $ 122 $ 22 $ 924 $ — $ — $ 924 Natural gas liquids revenue 46 — — — 46 — — 46 Natural gas revenue 34 2 5 160 201 — — 201 Sales of purchased oil and gas 381 — 23 3 407 — — 407 Intercompany revenue — — — — — 215 (215 ) — Total revenues from contracts with customers 1,210 33 150 185 1,578 215 (215 ) 1,578 Other operating revenues (a) 2 — — — 2 — — 2 Total sales and other operating revenues $ 1,212 $ 33 $ 150 $ 185 $ 1,580 $ 215 $ (215 ) $ 1,580 Three Months Ended September 30, 2018 Sales of our net production volumes: Crude oil revenue $ 826 $ 54 $ 108 $ 29 $ 1,017 $ — $ — $ 1,017 Natural gas liquids revenue 90 — — — 90 — — 90 Natural gas revenue 44 3 5 178 230 — — 230 Sales of purchased oil and gas 482 — 22 — 504 — — 504 Intercompany revenue — — — — — 184 (184 ) — Total revenues from contracts with customers 1,442 57 135 207 1,841 184 (184 ) 1,841 Other operating revenues (a) (48 ) — — — (48 ) — — (48 ) Total sales and other operating revenues $ 1,394 $ 57 $ 135 $ 207 $ 1,793 $ 184 $ (184 ) $ 1,793 (a) Includes gains (losses) on commodity derivatives. Exploration and Production Midstream Eliminations Total United States Denmark Libya Malaysia & JDA E&P Total (In millions) Nine Months Ended September 30, 2019 Sales of our net production volumes: Crude oil revenue $ 2,193 $ 98 $ 343 $ 67 $ 2,701 $ — $ — $ 2,701 Natural gas liquids revenue 162 — — — 162 — — 162 Natural gas revenue 109 7 17 494 627 — — 627 Sales of purchased oil and gas 1,246 — 67 3 1,316 — — 1,316 Intercompany revenue — — — — — 595 (595 ) — Total revenues from contracts with customers 3,710 105 427 564 4,806 595 (595 ) 4,806 Other operating revenues (a) 6 — — — 6 — — 6 Total sales and other operating revenues $ 3,716 $ 105 $ 427 $ 564 $ 4,812 $ 595 $ (595 ) $ 4,812 Nine Months Ended September 30, 2018 Sales of our net production volumes: Crude oil revenue $ 2,111 $ 106 $ 317 $ 100 $ 2,634 $ — $ — $ 2,634 Natural gas liquids revenue 236 — — — 236 — — 236 Natural gas revenue 120 8 20 471 619 — — 619 Sales of purchased oil and gas 1,231 — 68 14 1,313 — — 1,313 Intercompany revenue — — — — — 527 (527 ) — Total revenues from contracts with customers 3,698 114 405 585 4,802 527 (527 ) 4,802 Other operating revenues (a) (129 ) — — — (129 ) — — (129 ) Total sales and other operating revenues $ 3,569 $ 114 $ 405 $ 585 $ 4,673 $ 527 $ (527 ) $ 4,673 (a) Includes gains (losses) on commodity derivatives. There have been no significant changes to contracts with customers or composition thereof during the nine months ended September 30, 2019. Generally, we receive payments from customers on a monthly basis, shortly after the physical delivery of the crude oil, natural gas liquids, or natural gas. We did not recognize any credit losses on receivables with customers during the first nine months of 2019 nor 2018.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Inventories	5. Inventories Inventories consisted of the following: September 30, December 31, 2019 2018 (In millions) Crude oil and natural gas liquids $ 72 $ 74 Materials and supplies 217 171 Total Inventories $ 289 $ 245

Capitalized Exploratory Well Co

Capitalized Exploratory Well Costs	9 Months Ended
	Sep. 30, 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 nine months ended September 30, 2019 (in millions): Balance at January 1, 2019 $ 418 Additions to capitalized exploratory well costs pending the determination of proved reserves 148 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (25 ) Balance at September 30, 2019 $ 541 The table above does not include well costs incurred and expensed during 2019 of $10 million associated with the Jill-1 well on License 6/16 (Hess 80%) in Denmark. Reclassifications to wells, facilities and equipment based on the determination of proved reserves resulted from sanction of the second phase of development for the Liza Field, offshore Guyana. Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $383 million at September 30, 2019 and primarily related to Guyana: Approximately 50% of the capitalized well costs in excess of one year relates to nine successful exploration wells where hydrocarbons were encountered on the Stabroek Block (Hess 30%), 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 on adjacent blocks to the north of our Shenzi blocks, the operator has commenced acquiring 3D seismic for use in development planning of the northern portion of the Shenzi Field. Joint Development Area (JDA): Approximately 10% of the capitalized well costs in excess of one year relates to the JDA (Hess 50%) in the Gulf of Thailand, where hydrocarbons were encountered in three successful exploration wells drilled in the western part of Block A-18. The operator 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 10% of the capitalized well costs in excess of one year relates to the North Malay Basin (Hess 50%), offshore Peninsular Malaysia, where hydrocarbons were encountered in five successful exploration wells. We are continuing to conduct subsurface evaluations for consideration in future phases of field development.

Hess Infrastructure Partners LP

Hess Infrastructure Partners LP	9 Months Ended
	Sep. 30, 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 September 30, 2019, the Midstream segment is comprised of HIP, which owns the general partner of Hess Midstream Partners LP ( In October 2019, Note 15, Subsequent Events 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- 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. At September 30, 2019, HIP liabilities totaling $1,308 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 $7 million (December 31, 2018: $109 million) and property, plant and equipment with a carrying value of $2,938 million (December 31, 2018: $2,664 million).

Dispositions

Dispositions	9 Months Ended
	Sep. 30, 2019
Disposition Of Businesses [Abstract]
Dispositions	8. Dispositions In the second quarter of 2019, we recorded a pre-tax gain of $22 million ($22 million after income taxes) associated with the sale of our remaining acreage in the Utica shale play. In the third quarter of 2018, we completed the sale of our joint venture interests in the Utica shale play for proceeds of $396 million, after normal closing adjustments, and recognized a pre-tax gain of $14 million ($14 million after income taxes).

Retirement Plans

Retirement Plans	9 Months Ended
	Sep. 30, 2019
Compensation And Retirement Disclosure [Abstract]
Retirement Plans	9. Retirement Plans Components of net periodic pension cost consisted of the following: Three Months Ended Nine Months Ended September 30, September 30, 2019 2018 2019 2018 (In millions) Service cost $ 12 $ 10 $ 33 $ 34 Interest cost (a) 23 24 71 71 Expected return on plan assets (a) (45 ) (49 ) (135 ) (147 ) Amortization of unrecognized net actuarial losses (a) 13 8 36 29 Settlement loss (a) 88 — 88 — Curtailment gains (a) — — — (2 ) Pension (income) expense (a) $ 91 $ (7 ) $ 93 $ (15 ) ( a) Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three and nine months ended September 30, 2019 was an expense of $79 million and $60 million, respectively, compared with income of $17 million and $49 million for the three and nine months ended September 30, 2018, respectively. In the third quarter of 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. Consolidated Balance Sheet. For the full year 2019, we now forecast pension service costs of approximately $45 million, interest cost of approximately $90 million, amortization of unrecognized net actuarial losses of approximately $50 million and estimated expected return on plan assets of approximately $180 million. In 2019, we expect to contribute $40 million to our funded pension plans. million.

Debt

Debt	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Debt	10. Debt Hess Corporation: In the second quarter of 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 had been due to mature on January 21, 2021. The new facility, which is fully undrawn, 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. Hess Midstream: In the three and nine months ended September 30, 2019, borrowings in the Midstream segment from revolving credit facilities were $16 million and $176 million, respectively.

Weighted Average Common Shares

Weighted Average Common Shares	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Weighted Average Common Shares	11. 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 Nine Months Ended September 30, September 30, 2019 2018 2019 2018 (In millions) Net income (loss) attributable to Hess Corporation Common Stockholders: Net income (loss) $ (166 ) $ 3 $ (57 ) $ (149 ) Less: Net income (loss) attributable to noncontrolling interests 46 45 129 129 Less: Preferred stock dividends — 11 4 34 Net income (loss) attributable to Hess Corporation Common Stockholders $ (212 ) $ (53 ) $ (190 ) $ (312 ) Weighted average number of common shares outstanding: Basic 302.5 294.3 300.7 300.4 Effect of dilutive securities Restricted common stock — — — — Stock options — — — — Performance share units — — — — Diluted 302.5 294.3 300.7 300.4 The following table summarizes the number of antidilutive shares excluded from the computation of diluted shares: Three Months Ended Nine Months Ended September 30, September 30, 2019 2018 2019 2018 Restricted common stock 2,074,913 2,898,733 2,272,234 2,890,171 Stock options 4,694,684 5,324,682 4,819,205 5,585,088 Performance share units 1,858,050 1,301,604 1,663,432 999,029 Common shares from conversion of preferred stock — 12,547,650 1,295,823 12,560,091 During the nine months ended September 30, 2019, we granted 959,168 shares of restricted stock (2018: 1,255,799), 234,866 performance share units (2018: 278,003) and 526,968 stock options (2018: 683,167).

Guarantees and Contingencies

Guarantees and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies Disclosure [Abstract]
Guarantees and Contingencies	12. 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. 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. 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. The EPA’s original estimate was that this remedy would cost $506 million 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.

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Segment Information	13. 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 September 30, 2019 Sales and Other Operating Revenues - Third parties $ 1,580 $ — $ — $ — $ 1,580 Intersegment Revenues — 215 — (215 ) — Sales and Other Operating Revenues $ 1,580 $ 215 $ — $ (215 ) $ 1,580 Net Income (Loss) attributable to Hess Corporation $ (60 ) $ 39 $ (191 ) $ — $ (212 ) Depreciation, Depletion and Amortization 507 36 1 — 544 Provision (Benefit) for Income Taxes (a) 116 — — — 116 Capital Expenditures 624 112 — — 736 For the Three Months Ended September 30, 2018 Sales and Other Operating Revenues - Third parties $ 1,793 $ — $ — $ — $ 1,793 Intersegment Revenues — 184 — (184 ) — Sales and Other Operating Revenues $ 1,793 $ 184 $ — $ (184 ) $ 1,793 Net Income (Loss) attributable to Hess Corporation $ 50 $ 30 $ (122 ) $ — $ (42 ) Depreciation, Depletion and Amortization 457 32 — — 489 Provision (Benefit) for Income Taxes (a) 100 10 11 — 121 Capital Expenditures 500 83 — — 583 For the Nine Months Ended September 30, 2019 Sales and Other Operating Revenues - Third parties $ 4,812 $ — $ — $ — $ 4,812 Intersegment Revenues — 595 — (595 ) — Sales and Other Operating Revenues $ 4,812 $ 595 $ — $ (595 ) $ 4,812 Net Income (Loss) attributable to Hess Corporation $ 117 $ 111 $ (414 ) $ — $ (186 ) Depreciation, Depletion and Amortization 1,430 105 1 — 1,536 Provision (Benefit) for Income Taxes (a) 342 — — — 342 Capital Expenditures 1,764 308 — — 2,072 For the Nine Months Ended September 30, 2018 Sales and Other Operating Revenues - Third parties $ 4,673 $ — $ — $ — $ 4,673 Intersegment Revenues — 527 — (527 ) — Sales and Other Operating Revenues $ 4,673 $ 527 $ — $ (527 ) $ 4,673 Net Income (Loss) attributable to Hess Corporation $ 56 $ 88 $ (422 ) $ — $ (278 ) Depreciation, Depletion and Amortization 1,249 94 7 — 1,350 Provision (Benefit) for Income Taxes (a) 300 28 (20 ) — 308 Capital Expenditures 1,340 204 — — 1,544 (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 Corporation 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, in the three and nine months ended September 30, 2018, Midstream segment net income attributable to Hess Corporation would have been $40 million and $116 million, respectively, and E&P segment net income attributable to Hess Corporation would have been $40 million and $28 million, respectively. Identifiable assets by operating segment were as follows: September 30, December 31, 2019 2018 (In millions) Exploration and Production $ 16,603 $ 16,109 Midstream 3,423 3,285 Corporate, Interest and Other 1,605 2,039 Total $ 21,631 $ 21,433

Financial Risk Management Activ

Financial Risk Management Activities	9 Months Ended
	Sep. 30, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Financial Risk Management Activities	14. 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 September 30, 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. 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 West Texas Intermediate (WTI) commodity contracts as of the dates shown below were as follows: September 30, 2019 December 31, 2018 Calendar year program 2019 2019 Contract type Puts Puts Effective date Oct. 1, 2019 Jan. 1, 2019 End date Dec. 31, 2019 Dec. 31, 2019 Crude oil volumes (millions of barrels) 8.7 34.7 Floor price per barrel – WTI $ 60 $ 60 In November 2019, the Corporation entered into WTI commodity contracts for 2020. See Note 15, Subsequent Events. The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows: September 30, 2019 December 31, 2018 (In millions) Foreign exchange $ 85 $ 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) September 30, 2019 Derivative Contracts Designated as Hedging Instruments: Commodity - Other current assets $ 68 $ — Interest rate - Other assets (noncurrent) 2 — Total derivative contracts designated as hedging instruments 70 — 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 71 — Master netting arrangements — — Net Fair Value of Derivative Contracts $ 71 $ — 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: In the three and nine months ended September 30, 2019, crude oil hedging contracts increased Sales and other operating revenues by $2 million and $3 million , respectively. Crude oil price hedging contracts for the three and nine months ended September 30, 2018 decreased Sales and other operating revenues by $45 million and $119 million, respectively. At September 30, 2019, pre-tax deferred gains in related to outstanding crude oil price hedging contracts were $ 27 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 September 30, 2019 and December 31, 2018, we had interest rate swaps with gross notional amounts totaling $100 million, which were designated as fair value hedges 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 in the . For the three and nine months ended September 30, 2019, the change in fair value of interest rate swaps was a decrease in the liability of $1 million and $4 million, respectively, compared with an increase in liability of less than $1 million and $4 million in the three and nine months ended September 30, 2018, respectively, with a corresponding adjustment in the carrying value of the hedged fixed-rate debt. Derivative contracts not designated as hedging instruments: Foreign exchange: Foreign exchange gains and losses which are reported in Other, net in the Statement of Consolidated Income were gains of $1 million and $4 million in the three and nine months ended September 30, 2019, respectively, compared with losses of $4 million in both the three and nine months ended September 30, 2018. A component of foreign exchange gains and losses are the results of foreign exchange derivative contracts that are not designated as hedges which amounted to gains of $1 million and $2 million in the three and nine months ended September 30, 2019, respectively, compared with losses of less than $1 million and $1 million in the three and nine months ended September 30, 2018, respectively. Crude oil derivatives: In the three and nine months ended September 30, 2018, noncash adjustments to de-designated crude oil price hedging contracts decreased Sales and other operating revenues by $4 million and $20 million, respectively. 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 September 30, 2019. At September 30, 2019, total long-term debt, which was substantially comprised of fixed-rate debt instruments, had a carrying value of $6,541 million and a fair value of $7,415 million based on Level 2 inputs.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
Subsequent Events	15. Subsequent Events On October 4, 2019, HESM announced that it will acquire HIP, including HIP’s 80% interest in HESM’s oil and gas midstream assets, HIP’s water services business and the outstanding economic general partner interest and incentive distribution rights in HESM. In addition, HESM’s organizational structure will convert from a master limited partnership into an “Up-C” structure in which HESM’s public unitholders will receive newly issued securities in a new public entity to be named “Hess Midstream LP” (Hess Midstream), which will be taxed as a corporation for U.S. Federal and State income tax purposes. As part of the proposed transaction between HESM and HIP, Hess Corporation announced it would receive approximately $275 million in cash and approximately 115 million newly issued units in HESM. Upon completion of the transaction, Hess Corporation will own approximately 134 million HESM units, or 47% of Hess Midstream on a consolidated basis. The transaction, which is non-taxable to Hess Corporation, is expected to close in the fourth quarter of 2019, subject to customary closing conditions and regulatory approvals. In November 2019, we entered into WTI crude oil price collars with an average monthly floor price of $50 per barrel and an average monthly ceiling price of $70 per barrel with a notional amount of 80,000 bopd for the full year 2020 at a cost of $78 million.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 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 with 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)

Basis of Presentation (Tables)	9 Months Ended
	Sep. 30, 2019
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Schedule of Impact of adoption on Consolidated Balance Sheet	The adoption of ASC 842 did not have an impact on our Statement of Consolidated Income Statement of Consolidated Cash Flows 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)

Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Schedule of Balance Sheet Information Related to Operating and Finance Leases	Operating and finance leases presented on the Consolidated Balance Sheet Operating Leases Finance Leases (In millions) Right-of-use assets - net (a) $ 527 $ 308 Lease obligations: Current $ 243 $ 16 Long-term 372 242 Total lease obligations $ 615 $ 258 (a) Finance lease ROU assets have a cost of $381 million and accumulated amortization of $73 million.
Schedule of Maturities of Lease Obligations	Maturities of lease obligations at September 30, 2019 were as follows: Operating Leases Finance Leases (In millions) 2019 $ 104 $ 9 2020 186 36 2021 70 36 2022 63 36 2023 63 36 Remaining years 199 248 Total lease payments 685 401 Less: Imputed interest (70 ) (143 ) Total lease obligations $ 615 $ 258
Summary of Information Relates to Operating and Finance Leases Recorded	The following information relates to the Operating and Finance leases recorded at September 30, 2019: Operating Leases Finance Leases Weighted average remaining lease term 5.1 years 14.0 years Range of remaining lease terms 0.2 - 16.3 years 14.0 years Weighted average discount rate 4.3% 7.9%
Schedule of Components of Lease Cost	The components of lease costs were as follows: Three Months Ended Nine Months Ended September 30, 2019 (In millions) Operating lease cost $ 102 $ 312 Finance lease cost: Amortization of leased assets 10 34 Interest on lease obligations 5 16 Short-term lease cost (a) 45 116 Variable lease cost (b) 22 62 Sublease income (c) (3 ) (9 ) Total lease cost $ 181 $ 531 (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.
Supplemental Cash Flow Information Related to Leases	Supplemental cash flow information related to leases for the nine months ended September 30, 2019 was as follows: Operating Leases Finance Leases (In millions) Cash paid for amounts included in the measurement of lease obligations (a): Operating cash flows $ 314 $ 16 Financing cash flows — 52 Noncash transactions: Leased assets recognized for new lease obligations incurred 10 — (a) Amounts represent gross lease payments before any recovery from partners.

Revenue (Tables)

Revenue (Tables)	9 Months Ended
	Sep. 30, 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: Exploration and Production Midstream Eliminations Total United States Denmark Libya Malaysia & JDA E&P Total (In millions) Three Months Ended September 30, 2019 Sales of our net production volumes: Crude oil revenue $ 749 $ 31 $ 122 $ 22 $ 924 $ — $ — $ 924 Natural gas liquids revenue 46 — — — 46 — — 46 Natural gas revenue 34 2 5 160 201 — — 201 Sales of purchased oil and gas 381 — 23 3 407 — — 407 Intercompany revenue — — — — — 215 (215 ) — Total revenues from contracts with customers 1,210 33 150 185 1,578 215 (215 ) 1,578 Other operating revenues (a) 2 — — — 2 — — 2 Total sales and other operating revenues $ 1,212 $ 33 $ 150 $ 185 $ 1,580 $ 215 $ (215 ) $ 1,580 Three Months Ended September 30, 2018 Sales of our net production volumes: Crude oil revenue $ 826 $ 54 $ 108 $ 29 $ 1,017 $ — $ — $ 1,017 Natural gas liquids revenue 90 — — — 90 — — 90 Natural gas revenue 44 3 5 178 230 — — 230 Sales of purchased oil and gas 482 — 22 — 504 — — 504 Intercompany revenue — — — — — 184 (184 ) — Total revenues from contracts with customers 1,442 57 135 207 1,841 184 (184 ) 1,841 Other operating revenues (a) (48 ) — — — (48 ) — — (48 ) Total sales and other operating revenues $ 1,394 $ 57 $ 135 $ 207 $ 1,793 $ 184 $ (184 ) $ 1,793 (a) Includes gains (losses) on commodity derivatives. Exploration and Production Midstream Eliminations Total United States Denmark Libya Malaysia & JDA E&P Total (In millions) Nine Months Ended September 30, 2019 Sales of our net production volumes: Crude oil revenue $ 2,193 $ 98 $ 343 $ 67 $ 2,701 $ — $ — $ 2,701 Natural gas liquids revenue 162 — — — 162 — — 162 Natural gas revenue 109 7 17 494 627 — — 627 Sales of purchased oil and gas 1,246 — 67 3 1,316 — — 1,316 Intercompany revenue — — — — — 595 (595 ) — Total revenues from contracts with customers 3,710 105 427 564 4,806 595 (595 ) 4,806 Other operating revenues (a) 6 — — — 6 — — 6 Total sales and other operating revenues $ 3,716 $ 105 $ 427 $ 564 $ 4,812 $ 595 $ (595 ) $ 4,812 Nine Months Ended September 30, 2018 Sales of our net production volumes: Crude oil revenue $ 2,111 $ 106 $ 317 $ 100 $ 2,634 $ — $ — $ 2,634 Natural gas liquids revenue 236 — — — 236 — — 236 Natural gas revenue 120 8 20 471 619 — — 619 Sales of purchased oil and gas 1,231 — 68 14 1,313 — — 1,313 Intercompany revenue — — — — — 527 (527 ) — Total revenues from contracts with customers 3,698 114 405 585 4,802 527 (527 ) 4,802 Other operating revenues (a) (129 ) — — — (129 ) — — (129 ) Total sales and other operating revenues $ 3,569 $ 114 $ 405 $ 585 $ 4,673 $ 527 $ (527 ) $ 4,673 (a) Includes gains (losses) on commodity derivatives.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Inventories	Inventories consisted of the following: September 30, December 31, 2019 2018 (In millions) Crude oil and natural gas liquids $ 72 $ 74 Materials and supplies 217 171 Total Inventories $ 289 $ 245

Capitalized Exploratory Well _2

Capitalized Exploratory Well Costs (Tables)	9 Months Ended
	Sep. 30, 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 nine months ended September 30, 2019 (in millions): Balance at January 1, 2019 $ 418 Additions to capitalized exploratory well costs pending the determination of proved reserves 148 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (25 ) Balance at September 30, 2019 $ 541

Retirement Plans (Tables)

Retirement Plans (Tables)	9 Months Ended
	Sep. 30, 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 Nine Months Ended September 30, September 30, 2019 2018 2019 2018 (In millions) Service cost $ 12 $ 10 $ 33 $ 34 Interest cost (a) 23 24 71 71 Expected return on plan assets (a) (45 ) (49 ) (135 ) (147 ) Amortization of unrecognized net actuarial losses (a) 13 8 36 29 Settlement loss (a) 88 — 88 — Curtailment gains (a) — — — (2 ) Pension (income) expense (a) $ 91 $ (7 ) $ 93 $ (15 ) ( a) Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three and nine months ended September 30, 2019 was an expense of $79 million and $60 million, respectively, compared with income of $17 million and $49 million for the three and nine months ended September 30, 2018, respectively.

Weighted Average Common Shares

Weighted Average Common Shares (Tables)	9 Months Ended
	Sep. 30, 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 Nine Months Ended September 30, September 30, 2019 2018 2019 2018 (In millions) Net income (loss) attributable to Hess Corporation Common Stockholders: Net income (loss) $ (166 ) $ 3 $ (57 ) $ (149 ) Less: Net income (loss) attributable to noncontrolling interests 46 45 129 129 Less: Preferred stock dividends — 11 4 34 Net income (loss) attributable to Hess Corporation Common Stockholders $ (212 ) $ (53 ) $ (190 ) $ (312 ) Weighted average number of common shares outstanding: Basic 302.5 294.3 300.7 300.4 Effect of dilutive securities Restricted common stock — — — — Stock options — — — — Performance share units — — — — Diluted 302.5 294.3 300.7 300.4
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 Nine Months Ended September 30, September 30, 2019 2018 2019 2018 Restricted common stock 2,074,913 2,898,733 2,272,234 2,890,171 Stock options 4,694,684 5,324,682 4,819,205 5,585,088 Performance share units 1,858,050 1,301,604 1,663,432 999,029 Common shares from conversion of preferred stock — 12,547,650 1,295,823 12,560,091

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2019 Sales and Other Operating Revenues - Third parties $ 1,580 $ — $ — $ — $ 1,580 Intersegment Revenues — 215 — (215 ) — Sales and Other Operating Revenues $ 1,580 $ 215 $ — $ (215 ) $ 1,580 Net Income (Loss) attributable to Hess Corporation $ (60 ) $ 39 $ (191 ) $ — $ (212 ) Depreciation, Depletion and Amortization 507 36 1 — 544 Provision (Benefit) for Income Taxes (a) 116 — — — 116 Capital Expenditures 624 112 — — 736 For the Three Months Ended September 30, 2018 Sales and Other Operating Revenues - Third parties $ 1,793 $ — $ — $ — $ 1,793 Intersegment Revenues — 184 — (184 ) — Sales and Other Operating Revenues $ 1,793 $ 184 $ — $ (184 ) $ 1,793 Net Income (Loss) attributable to Hess Corporation $ 50 $ 30 $ (122 ) $ — $ (42 ) Depreciation, Depletion and Amortization 457 32 — — 489 Provision (Benefit) for Income Taxes (a) 100 10 11 — 121 Capital Expenditures 500 83 — — 583 For the Nine Months Ended September 30, 2019 Sales and Other Operating Revenues - Third parties $ 4,812 $ — $ — $ — $ 4,812 Intersegment Revenues — 595 — (595 ) — Sales and Other Operating Revenues $ 4,812 $ 595 $ — $ (595 ) $ 4,812 Net Income (Loss) attributable to Hess Corporation $ 117 $ 111 $ (414 ) $ — $ (186 ) Depreciation, Depletion and Amortization 1,430 105 1 — 1,536 Provision (Benefit) for Income Taxes (a) 342 — — — 342 Capital Expenditures 1,764 308 — — 2,072 For the Nine Months Ended September 30, 2018 Sales and Other Operating Revenues - Third parties $ 4,673 $ — $ — $ — $ 4,673 Intersegment Revenues — 527 — (527 ) — Sales and Other Operating Revenues $ 4,673 $ 527 $ — $ (527 ) $ 4,673 Net Income (Loss) attributable to Hess Corporation $ 56 $ 88 $ (422 ) $ — $ (278 ) Depreciation, Depletion and Amortization 1,249 94 7 — 1,350 Provision (Benefit) for Income Taxes (a) 300 28 (20 ) — 308 Capital Expenditures 1,340 204 — — 1,544 (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 Corporation 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, in the three and nine months ended September 30, 2018, Midstream segment net income attributable to Hess Corporation would have been $40 million and $116 million, respectively, and E&P segment net income attributable to Hess Corporation would have been $40 million and $28 million, respectively. Identifiable assets by operating segment were as follows: September 30, December 31, 2019 2018 (In millions) Exploration and Production $ 16,603 $ 16,109 Midstream 3,423 3,285 Corporate, Interest and Other 1,605 2,039 Total $ 21,631 $ 21,433

Financial Risk Management Act_2

Financial Risk Management Activities (Tables)	9 Months Ended
	Sep. 30, 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) September 30, 2019 Derivative Contracts Designated as Hedging Instruments: Commodity - Other current assets $ 68 $ — Interest rate - Other assets (noncurrent) 2 — Total derivative contracts designated as hedging instruments 70 — 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 71 — Master netting arrangements — — Net Fair Value of Derivative Contracts $ 71 $ — 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 )
Related to West Texas Intermediate (WTI) Instruments
Derivative Instruments Gain Loss [Line Items]
Summary of Gross Notional Amounts of Outstanding West Texas Intermediate (WTI) Commodity Contracts	The gross notional amounts of outstanding West Texas Intermediate (WTI) commodity contracts as of the dates shown below were as follows: September 30, 2019 December 31, 2018 Calendar year program 2019 2019 Contract type Puts Puts Effective date Oct. 1, 2019 Jan. 1, 2019 End date Dec. 31, 2019 Dec. 31, 2019 Crude oil volumes (millions of barrels) 8.7 34.7 Floor price per barrel – WTI $ 60 $ 60
Excluding West Texas Intermediate (WTI)
Derivative Instruments Gain Loss [Line Items]
Gross Notional Amounts of Outstanding Financial Risk Management Derivative Contracts	In November 2019, the Corporation entered into WTI commodity contracts for 2020. See Note 15, Subsequent Events. The gross notional amounts of outstanding financial risk management derivative contracts, excluding commodity contracts, were as follows: September 30, 2019 December 31, 2018 (In millions) Foreign exchange $ 85 $ 16 Interest rate swaps $ 100 $ 100

Basis of Presentation - Additio

Basis of Presentation - Additional Information (Detail) - USD ($) $ in Millions	Jan. 01, 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 - Schedul

Basis of Presentation - Schedule of Impact of adoption on Consolidated Balance Sheet (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Assets
Property, plant and equipment — net	$ 16,449		$ 16,083
Operating lease right-of-use assets — net	527		0
Finance lease right-of-use assets — net	308		0
Liabilities
Accrued liabilities	1,570		1,560
Current maturities of long-term debt	15		67
Current portion of operating and finance lease obligations	259		0
Long-term debt	6,526		6,605
Long-term operating lease obligations	372		0
Long-term finance lease obligations	242		0
Other liabilities and deferred credits	$ 709		$ 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 Consolidat

Leases - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease right-of-use assets — net	$ 527	$ 0
Operating Leases, Lease obligations:
Operating Leases, Lease Liabilities, Current	243
Long-term operating lease obligations	372	0
Operating Leases, Total lease obligations	615
Finance lease right-of-use assets — net	308	0
Financing Leases, Lease obligations:
Financing Leases, Lease liabilities, Current	16
Financing Leases, Lease liabilities, Long-term	242	$ 0
Financing Leases, Total lease obligations	$ 258

Leases - Schedule of Consolid_2

Leases - Schedule of Consolidated Balance Sheet Information Related to Operating and Finance Leases (Parenthetical) (Detail) $ in Millions	Sep. 30, 2019USD ($)
Leases [Abstract]
Finance lease, right-of-use assets, amortization cost	$ 381
Finance lease, right-of-use assets, accumulated amortization	$ 73

Leases - Additional Information

Leases - Additional Information (Detail) - USD ($)	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Leases [Line Items]
Lease obligations as percentage of present value of future minimum lease payments in lease arrangement		100.00%
Proceeds from asset sales, net of cash sold		$ 22,000,000	$ 607,000,000
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%	50.00%
Proceeds from asset sales, net of cash sold	$ 260,000,000		$ 260,000,000
Gain or loss on sale of transaction	$ 0		$ 0
Finance lease term		14 years

Leases - Schedule of Maturities

Leases - Schedule of Maturities of Lease Obligations (Detail) $ in Millions	Sep. 30, 2019USD ($)
Leases [Abstract]
Operating Leases, 2019	$ 104
Operating Leases, 2020	186
Operating Leases, 2021	70
Operating Leases, 2022	63
Operating Leases, 2023	63
Operating Leases, Remaining years	199
Total lease payments	685
Less: Imputed interest	(70)
Total lease obligations	615
Financing Leases, 2019	9
Financing Leases, 2020	36
Financing Leases, 2021	36
Financing Leases, 2022	36
Financing Leases, 2023	36
Financing Leases, Remaining years	248
Total lease payments	401
Less: Imputed interest	(143)
Total lease obligations	$ 258

Leases - Summary of Information

Leases - Summary of Information Relates to Operating and Finance Leases Recorded (Detail)	9 Months Ended
	Sep. 30, 2019
Leases [Line Items]
Operating leases, Weighted average remaining lease term	5 years 1 month 6 days
Operating leases, Weighted average discount rate	4.30%
Finance leases, Weighted average remaining lease term	14 years
Finance leases, Range of remaining lease terms	14 years
Finance leases, Weighted average discount rate	7.90%
Minimum
Leases [Line Items]
Operating leases, Range of remaining lease terms	2 months 12 days
Maximum
Leases [Line Items]
Operating leases, Range of remaining lease terms	16 years 3 months 18 days

Leases - Components of Lease Co

Leases - Components of Lease Costs (Detail) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Leases [Abstract]
Operating lease cost	$ 102	$ 312
Finance lease cost:
Amortization of leased assets	10	34
Interest on lease obligations	5	16
Short-term lease cost	45	116
Variable lease cost	22	62
Sublease income	(3)	(9)
Total lease cost	$ 181	$ 531

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flow Information Related to Leases (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Cash paid for amounts included in the measurement of lease obligations:
Operating Leases, Operating cash flows	$ 314
Operating Leases, Financing cash flows	0
Finance Leases, Operating cash flows	16
Finance Leases, Financing cash flows	52
Noncash transactions:
Operating Leases, Leased assets recognized for new lease obligations incurred	10
Finance Leases, Leased assets recognized for new lease obligations incurred	$ 0

Preferred Stock Conversion - Ad

Preferred Stock Conversion - Additional Information (Detail) - shares shares in Millions	Jan. 31, 2019	Sep. 30, 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	12.5
Series A, cumulative mandatory convertible preferred stock - dividend rate	8.00%	8.00%
Number of common shares received from capped call upon conversion of preferred stocks	0.9	0.9
Net number of common shares issued upon conversion of preferred stocks	11.6	11.6
Convertible preferred stock conversion in to common stock converted shares		21.822

Revenue - Summary of Revenue fr

Revenue - Summary of Revenue from Contracts with Customers on a Disaggregated Basis (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	$ 1,578	$ 1,841	$ 4,806	$ 4,802
Other operating revenues (a)	2	(48)	6	(129)
Total sales and other operating revenues	1,580	1,793	4,812	4,673
Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	924	1,017	2,701	2,634
Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	46	90	162	236
Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	201	230	627	619
Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	407	504	1,316	1,313
Operating Segments | Exploration and Production
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	1,578	1,841	4,806	4,802
Other operating revenues (a)	2	(48)	6	(129)
Total sales and other operating revenues	1,580	1,793	4,812	4,673
Operating Segments | Exploration and Production | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	1,210	1,442	3,710	3,698
Other operating revenues (a)	2	(48)	6	(129)
Total sales and other operating revenues	1,212	1,394	3,716	3,569
Operating Segments | Exploration and Production | United States | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Denmark
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	33	57	105	114
Other operating revenues (a)	0	0	0	0
Total sales and other operating revenues	33	57	105	114
Operating Segments | Exploration and Production | Denmark | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Libya
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	150	135	427	405
Other operating revenues (a)	0	0	0	0
Total sales and other operating revenues	150	135	427	405
Operating Segments | Exploration and Production | Libya | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Malaysia & JDA
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	185	207	564	585
Other operating revenues (a)	0	0	0	0
Total sales and other operating revenues	185	207	564	585
Operating Segments | Exploration and Production | Malaysia & JDA | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	924	1,017	2,701	2,634
Operating Segments | Exploration and Production | Crude Oil Revenue | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	749	826	2,193	2,111
Operating Segments | Exploration and Production | Crude Oil Revenue | Denmark
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	31	54	98	106
Operating Segments | Exploration and Production | Crude Oil Revenue | Libya
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	122	108	343	317
Operating Segments | Exploration and Production | Crude Oil Revenue | Malaysia & JDA
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	22	29	67	100
Operating Segments | Exploration and Production | Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	46	90	162	236
Operating Segments | Exploration and Production | Natural Gas Liquids Revenue | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	46	90	162	236
Operating Segments | Exploration and Production | Natural Gas Liquids Revenue | Denmark
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Natural Gas Liquids Revenue | Libya
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Natural Gas Liquids Revenue | Malaysia & JDA
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	201	230	627	619
Operating Segments | Exploration and Production | Natural Gas Revenue | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	34	44	109	120
Operating Segments | Exploration and Production | Natural Gas Revenue | Denmark
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	2	3	7	8
Operating Segments | Exploration and Production | Natural Gas Revenue | Libya
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	5	5	17	20
Operating Segments | Exploration and Production | Natural Gas Revenue | Malaysia & JDA
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	160	178	494	471
Operating Segments | Exploration and Production | Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	407	504	1,316	1,313
Operating Segments | Exploration and Production | Sales of Purchased Oil and Gas | United States
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	381	482	1,246	1,231
Operating Segments | Exploration and Production | Sales of Purchased Oil and Gas | Denmark
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production | Sales of Purchased Oil and Gas | Libya
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	23	22	67	68
Operating Segments | Exploration and Production | Sales of Purchased Oil and Gas | Malaysia & JDA
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	3	0	3	14
Operating Segments | Midstream
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	215	184	595	527
Other operating revenues (a)	0	0	0	0
Total sales and other operating revenues	215	184	595	527
Operating Segments | Midstream | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	215	184	595	527
Operating Segments | Midstream | Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream | Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream | Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream | Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	(215)	(184)	(595)	(527)
Other operating revenues (a)	0	0	0	0
Total sales and other operating revenues	(215)	(184)	(595)	(527)
Eliminations | Intercompany Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	(215)	(184)	(595)	(527)
Eliminations | Crude Oil Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Natural Gas Liquids Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Natural Gas Revenue
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Sales of Purchased Oil and Gas
Disaggregation Of Revenue [Line Items]
Total revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

Revenue - Additional Informatio

Revenue - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Exploration and Production
Disaggregation Of Revenue [Line Items]
Credit losses on receivables with customers	$ 0

Inventories - Inventories (Deta

Inventories - Inventories (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 72	$ 74
Materials and supplies	217	171
Total Inventories	$ 289	$ 245

Capitalized Exploratory Well _3

Capitalized Exploratory Well Costs - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Capitalized Exploratory Well Costs [Abstract]
Beginning balance	$ 418
Additions to capitalized exploratory well costs pending the determination of proved reserves	148
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(25)
Ending balance	$ 541

Capitalized Exploratory Well _4

Capitalized Exploratory Well Costs - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Capitalized Exploratory Well Costs [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 383
Jill-1 well on License 6/16 in Denmark
Capitalized Exploratory Well Costs [Line Items]
Cost incurred on unsuccessful exploration wells	$ 10
Project interest percentage	80.00%
Successful Exploration Wells on the Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	30.00%
Capitalized well costs percentage	50.00%
Northern Portion of Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	28.00%
Capitalized well costs percentage	30.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	50.00%
Capitalized well costs percentage	10.00%
North Malay Basin, offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	10.00%
Project interest percentage	50.00%

Hess Infrastructure Partners _2

Hess Infrastructure Partners LP - Additional Information (Detail) - USD ($) $ in Millions	Mar. 22, 2019	Mar. 01, 2019	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entity [Line Items]
Cash and cash equivalents			$ 1,863	$ 2,694	$ 3,004	$ 4,847
Property, plant and equipment, net			$ 16,449	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			$ 7	109
Property, plant and equipment, net			2,938	2,664
HIP's liabilities on a nonrecourse to Hess Corporation			$ 1,308	$ 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%

Dispositions - Additional Infor

Dispositions - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain (loss) on asset sales, pre-tax	$ 0		$ 14	$ 22	$ 32
Proceeds from asset sales				22	607
Utica Shale Play
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain (loss) on asset sales, pre-tax		$ 22	14	22	14
Gain (loss) on asset sale, after-tax		$ 22	14	$ 22	14
Proceeds from asset sales			$ 396		$ 396

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Corporation's estimated contribution for funded pension plans in 2019	$ 40		$ 40
Corporation's contribution for funded pension plan during the year to date			20
Settlement loss	88	$ 0	88	$ 0
Service cost	12	10	33	34
Interest cost	23	24	71	71
Amortization of unrecognized net actuarial losses	13	8	36	29
Expected return on plan assets	45	$ 49	135	$ 147
Scenario Forecast
Defined Benefit Plan Disclosure [Line Items]
Service cost					$ 45
Interest cost					90
Amortization of unrecognized net actuarial losses					50
Expected return on plan assets					$ 180
Hess Corporation Employees’ Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Settlement loss	88		88
Single premium annuity contract cost	250		250
Net increase in post retirement plan liabilities	$ 239		$ 239

Retirement Plans - Components o

Retirement Plans - Components of Net Periodic Pension Cost (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Compensation And Retirement Disclosure [Abstract]
Service cost	$ 12	$ 10	$ 33	$ 34
Interest cost	23	24	71	71
Expected return on plan assets	(45)	(49)	(135)	(147)
Amortization of unrecognized net actuarial losses	13	8	36	29
Settlement loss	88	0	88	0
Curtailment gains	0	0	0	(2)
Pension (income) expense	$ 91	$ (7)	$ 93	$ (15)

Retirement Plans - Components_2

Retirement Plans - Components of Net Periodic Pension Cost (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Compensation And Retirement Disclosure [Abstract]
Net non-service pension (income) costs included in Other, net	$ 79	$ (17)	$ 60	$ (49)

Debt - Additional Information (

Debt - Additional Information (Detail) - Revolving Credit Facility - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2019
Debt Instrument Redemption [Line Items]
Debt Instrument, undrawn borrowing capacity, amount		$ 3,500
Debt instrument maturity year		May 15, 2023	May 15, 2023
Debt instrument covenant, description		1.30%
Debt instrument covenant, ratio		65.00%
Revolving credit facility expiration date		Jan. 21, 2021	Jan. 21, 2021
Hess Midstream
Debt Instrument Redemption [Line Items]
Borrowings from revolving credit line	$ 16		$ 176

Weighted Average Common Share_2

Weighted Average Common Shares - Basic and Diluted Earnings Per Share (Detail) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net income (loss)	$ (166)	$ 3	$ (57)	$ (149)
Less: Net income (loss) attributable to noncontrolling interests	46	45	129	129
Less: Preferred stock dividends	0	11	4	34
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$ (212)	$ (53)	$ (190)	$ (312)
Weighted average number of common shares outstanding:
Basic	302.5	294.3	300.7	300.4
Diluted	302.5	294.3	300.7	300.4
Restricted Common Stock
Weighted average number of common shares outstanding:
Effect of dilutive securities	0	0	0	0
Stock Options
Weighted average number of common shares outstanding:
Effect of dilutive securities	0	0	0	0
Performance Share Units
Weighted average number of common shares outstanding:
Effect of dilutive securities	0	0	0	0

Weighted Average Common Share_3

Weighted Average Common Shares - Antidilutive Shares Excluded from Computation of Diluted Shares (Detail) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Restricted Common Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	2,074,913	2,898,733	2,272,234	2,890,171
Stock Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	4,694,684	5,324,682	4,819,205	5,585,088
Performance Share Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	1,858,050	1,301,604	1,663,432	999,029
Common Shares from Conversion of Preferred Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares	0	12,547,650	1,295,823	12,560,091

Weighted Average Common Share_4

Weighted Average Common Shares - Additional Information (Detail) - shares	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Equity [Abstract]
Shares granted, restricted stock	959,168	1,255,799
Shares granted, performance share units	234,866	278,003
Shares granted, stock options	526,968	683,167

Guarantees and Contingencies -

Guarantees and Contingencies - Additional Information (Detail) $ in Millions	Mar. 04, 2016USD ($)	Mar. 31, 2014USD ($)	Sep. 30, 2019Case
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

Segment Information - Additiona

Segment Information - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2019Segment
Segment Reporting [Abstract]
Number of operating segments for the Corporation	2

Segment Information - Financial

Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	$ 1,580	$ 1,793	$ 4,812	$ 4,673
Intersegment revenues	0	0	0	0
Total sales and other operating revenues	1,580	1,793	4,812	4,673
Net Income (Loss) attributable to Hess Corporation	(212)	(42)	(186)	(278)
Depreciation, depletion and amortization	544	489	1,536	1,350
Provision (benefit) for income taxes	116	121	342	308
Capital Expenditures	736	583	2,072	1,544
Identifiable assets	21,631		21,631		$ 21,433
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0	0
Intersegment revenues	(215)	(184)	(595)	(527)
Total sales and other operating revenues	(215)	(184)	(595)	(527)
Net Income (Loss) attributable to Hess Corporation	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Provision (benefit) for income taxes	0	0	0	0
Capital Expenditures	0	0	0	0
Exploration and Production | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	1,580	1,793	4,812	4,673
Intersegment revenues	0	0	0	0
Total sales and other operating revenues	1,580	1,793	4,812	4,673
Net Income (Loss) attributable to Hess Corporation	(60)	50	117	56
Depreciation, depletion and amortization	507	457	1,430	1,249
Provision (benefit) for income taxes	116	100	342	300
Capital Expenditures	624	500	1,764	1,340
Identifiable assets	16,603		16,603		16,109
Midstream | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0	0
Intersegment revenues	215	184	595	527
Total sales and other operating revenues	215	184	595	527
Net Income (Loss) attributable to Hess Corporation	39	30	111	88
Depreciation, depletion and amortization	36	32	105	94
Provision (benefit) for income taxes	0	10	0	28
Capital Expenditures	112	83	308	204
Identifiable assets	3,423		3,423		3,285
Corporate, Interest and Other | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues - third-parties	0	0	0	0
Intersegment revenues	0	0	0	0
Total sales and other operating revenues	0	0	0	0
Net Income (Loss) attributable to Hess Corporation	(191)	(122)	(414)	(422)
Depreciation, depletion and amortization	1	0	1	7
Provision (benefit) for income taxes	0	11	0	(20)
Capital Expenditures	0	$ 0	0	$ 0
Identifiable assets	$ 1,605		$ 1,605		$ 2,039

Segment Information - Financi_2

Segment Information - Financial Data by Operating Segment (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	$ (212)	$ (42)	$ (186)	$ (278)
Midstream Segment | Operating Segments
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	39	30	111	88
Midstream Segment | Operating Segments | Pro Forma
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation		40		116
Exploration and Production | Operating Segments
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	$ (60)	50	$ 117	56
Exploration and Production | Operating Segments | Pro Forma
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation		$ 40		$ 28

Financial Risk Management Act_3

Financial Risk Management Activities - Summary of Gross Notional Amounts of Outstanding West Texas Intermediate (WTI) Commodity Contracts (Detail) - WTI - 2019	9 Months Ended	12 Months Ended
	Sep. 30, 2019MMBbls$ / bbl	Dec. 31, 2018MMBbls$ / bbl
Derivative [Line Items]
Calendar year program	2019	2019
Contract type	Puts	Puts
Effective date	Oct. 1, 2019	Jan. 1, 2019
End date	Dec. 31, 2019	Dec. 31, 2019
Crude oil volumes (millions of barrels) | MMBbls	8.7	34.7
Floor price per barrel – WTI | $ / bbl	60	60

Financial Risk Management Act_4

Financial Risk Management Activities - Gross Notional Amounts of Derivative Contracts Outstanding Excluding Commodity Contracts (Detail) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Foreign Exchange
Derivative [Line Items]
Outstanding gross notional amount	$ 85,000,000	$ 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 Act_5

Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 71	$ 484
Assets - Master netting arrangements	0	0
Assets - Net Fair Value of Derivative Contracts	71	484
Liabilities - Gross fair value of derivative contracts	0	(2)
Liabilities - Master netting arrangements	0	0
Liabilities - Net Fair Value of Derivative Contracts	0	(2)
Derivative Contracts Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	70	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	68	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	2
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	1
Liabilities - Gross fair value of derivative contracts	0
Derivative Contracts Not Designated as Hedging Instruments | Foreign Exchange
Derivatives Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	1
Liabilities - Gross fair value of derivative contracts	$ 0

Financial Risk Management Act_6

Financial Risk Management Activities - Additional Information (Detail) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Interest Rate Swaps | Designated as Fair Value Hedges
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	$ 100,000,000		$ 100,000,000		$ 100,000,000
Unrealized change in fair value of interest rate swaps - (increase) decrease in derivative liability	1,000,000		4,000,000	$ (4,000,000)
Interest Rate Swaps | Maximum | Designated as Fair Value Hedges
Derivative Instruments Gain Loss [Line Items]
Unrealized change in fair value of interest rate swaps - (increase) decrease in derivative liability		$ (1,000,000)
Foreign Exchange
Derivative Instruments Gain Loss [Line Items]
Outstanding gross notional amount	85,000,000		85,000,000		$ 16,000,000
Foreign exchange gains (losses) reported in Other, net in the Statement of Consolidated Income	1,000,000	(4,000,000)	4,000,000	(4,000,000)
Gains (Losses) on foreign exchange contracts not designated as hedging instruments	1,000,000		2,000,000	(1,000,000)
Foreign Exchange | Maximum
Derivative Instruments Gain Loss [Line Items]
Gains (Losses) 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]
Increased (decreased) sales and other operating revenue	$ 2,000,000	(45,000,000)	3,000,000	(119,000,000)
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings during the remainder of 2019			$ 27,000,000
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		$ (4,000,000)		$ (20,000,000)

Financial Risk Management Act_7

Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Sep. 30, 2019USD ($)
Carrying value
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt	$ 6,541
Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total long-term debt fair value	$ 7,415

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail) - Subsequent Event shares in Millions, $ in Millions	Oct. 04, 2019USD ($)shares	Nov. 30, 2019USD ($)bbl / d$ / bbl
Subsequent Event [Line Items]
Cash receivable upon proposed transaction | $	$ 275
WTI | 2020
Subsequent Event [Line Items]
Floor price per barrel – WTI | $ / bbl		50
Monthly ceiling price | $ / bbl		70
Notional amount of outstanding average barrels of oil per day | bbl / d		80,000
Cost of derivative | $		$ 78
Hess Midstream | Hess Infrastructure Partners LP (HIP) | Oil And Gas Midstream Assets
Subsequent Event [Line Items]
Percentage of ownership interest	80.00%
Hess Midstream
Subsequent Event [Line Items]
Units receivable upon proposed transaction | shares	115
Number of units own upon completion of transaction | shares	134
Percentage of Midstream owned by upon completion of transaction	47.00%