10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549 

Form 10-Q 

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarter ended June 30, 2020

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                      to                     

Commission File Number 1-1204 

HESS CORPORATION

(Exact Name of Registrant as Specified in Its Charter)

DELAWARE

(State or Other Jurisdiction of Incorporation or Organization)

13-4921002

(I.R.S. Employer Identification Number)

1185 AVENUE OF THE AMERICAS, NEW YORK, NY

(Address of Principal Executive Offices)

10036

(Zip Code)

(Registrant’s Telephone Number, Including Area Code is (212) 997-8500)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol	Name of exchange on which registered
Common Stock	HES	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  ý    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).   Yes  ☐  No  ý

At June 30, 2020, there were 307,144,424 shares of Common Stock outstanding.

HESS CORPORATION

Form 10-Q

TABLE OF CONTENTS

Item No.		Page Number
	PART I - FINANCIAL INFORMATION
1.	Financial Statements (Unaudited)
	Consolidated Balance Sheet at June 30, 2020, and December 31, 2019	2
	Statement of Consolidated Income for the Three and Six Months Ended June 30, 2020, and 2019	3
	Statement of Consolidated Comprehensive Income for the Three and Six Months Ended June 30, 2020, and 2019	4
	Statement of Consolidated Cash Flows for the Six Months Ended June 30, 2020, and 2019	5
	Statement of Consolidated Equity for the Three and Six Months Ended June 30, 2020, and 2019	6
	Notes to Consolidated Financial Statements (Unaudited)	7
	Note 1 - Basis of Presentation	7
	Note 2 - Inventories	7
	Note 3 - Property Plant and Equipment	7
	Note 4 - Hess Midstream LP	8
	Note 5 - Debt	8
	Note 6 - Revenue	9
	Note 7 - Impairment	10
	Note 8 - Retirement Plans	10
	Note 9 - Weighted Average Common Shares	11
	Note 10 - Guarantees and Contingencies	11
	Note 11 - Segment Information	13
	Note 12 - Financial Risk Management Activities	14
2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	16
3.	Quantitative and Qualitative Disclosures about Market Risk	31
4.	Controls and Procedures	31
	PART II - OTHER INFORMATION
1.	Legal Proceedings	32
1A.	Risk Factors	32
6.	Exhibits	33
	Signatures	34

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

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	June 30, 2020		December 31, 2019
	(In millions, except share amounts)
Assets
Current Assets:
Cash and cash equivalents	$	1,646	$	1,545
Accounts receivable:
From contracts with customers	428		940
Joint venture and other	168		230
Crude oil derivative contracts	450		125
Inventories	360		261
Other current assets	63		55
Total current assets	3,115		3,156
Property, plant and equipment:
Total — at cost	32,209		35,820
Less: Reserves for depreciation, depletion, amortization and lease impairment	17,384		19,006
Property, plant and equipment — net	14,825		16,814
Operating lease right-of-use assets — net	344		447
Finance lease right-of-use assets — net	182		299
Goodwill	360		360
Deferred income taxes	78		80
Other assets	642		626
Total Assets	$	19,546	$	21,782
Liabilities
Current Liabilities:
Accounts payable	$	307	$	411
Accrued liabilities	1,110		1,803
Taxes payable	34		97
Current maturities of long-term debt	5		—
Current portion of operating and finance lease obligations	108		199
Total current liabilities	1,564		2,510
Long-term debt	8,205		7,142
Long-term operating lease obligations	349		353
Long-term finance lease obligations	229		238
Deferred income taxes	319		415
Asset retirement obligations	944		897
Other liabilities and deferred credits	570		521
Total Liabilities	12,180		12,076
Equity
Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized — 600,000,000 shares
Issued — 307,144,424 shares (2019: 304,955,472)	307		305
Capital in excess of par value	5,650		5,591
Retained earnings	625		3,535
Accumulated other comprehensive income (loss)	(187)		(699)
Total Hess Corporation stockholders’ equity	6,395		8,732
Noncontrolling interests	971		974
Total Equity	7,366		9,706
Total Liabilities and Equity	$	19,546	$	21,782

See accompanying Notes to Consolidated Financial Statements.

2

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED INCOME (UNAUDITED)

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions, except per share amounts)
Revenues and Non-Operating Income
Sales and other operating revenues	$	833	$	1,660	$	2,187	$	3,232
Gains on asset sales, net	8		22		8		22
Other, net	1		15		16		42
Total revenues and non-operating income	842		1,697		2,211		3,296
Costs and Expenses
Marketing, including purchased oil and gas	56		477		434		885
Operating costs and expenses	294		285		597		551
Production and severance taxes	16		46		58		85
Exploration expenses, including dry holes and lease impairment	31		43		220		77
General and administrative expenses	89		89		191		176
Interest expense	119		97		232		195
Depreciation, depletion and amortization	509		494		1,070		992
Impairment	—		—		2,126		—
Total costs and expenses	1,114		1,531		4,928		2,961
Income (Loss) Before Income Taxes	(272)		166		(2,717)		335
Provision (benefit) for income taxes	(9)		132		(88)		226
Net Income (Loss)	(263)		34		(2,629)		109
Less: Net income (loss) attributable to noncontrolling interests	57		40		124		83
Net Income (Loss) Attributable to Hess Corporation	(320)		(6)		(2,753)		26
Less: Preferred stock dividends	—		—		—		4
Net Income (Loss) Attributable to Hess Corporation Common Stockholders	$	(320)	$	(6)	$	(2,753)	$	22
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$	(1.05)	$	(0.02)	$	(9.04)	$	0.07
Diluted	$	(1.05)	$	(0.02)	$	(9.04)	$	0.07
Weighted Average Number of Common Shares Outstanding:
Basic	305.0		302.2		304.5		299.8
Diluted	305.0		302.2		304.5		302.1
Common Stock Dividends Per Share	$	0.25	$	0.25	$	0.50	$	0.50

See accompanying Notes to Consolidated Financial Statements.

3

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Net Income (Loss)	$	(263)	$	34	$	(2,629)	$	109
Other Comprehensive Income (Loss):
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	(228)		14		(292)		(1)
Income taxes on effect of hedge (gains) losses reclassified to income	—		—		—		—
Net effect of hedge (gains) losses reclassified to income	(228)		14		(292)		(1)
Change in fair value of cash flow hedges	(214)		—		776		(346)
Income taxes on change in fair value of cash flow hedges	—		—		—		—
Net change in fair value of cash flow hedges	(214)		—		776		(346)
Change in derivatives designated as cash flow hedges, after taxes	(442)		14		484		(347)
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	4		(24)		4		(18)
Income taxes on actuarial changes in plan liabilities	—		—		—		—
(Increase) reduction in unrecognized actuarial losses, net	4		(24)		4		(18)
Amortization of net actuarial losses	12		12		24		23
Income taxes on amortization of net actuarial losses	—		—		—		—
Net effect of amortization of net actuarial losses	12		12		24		23
Change in pension and other postretirement plans, after taxes	16		(12)		28		5
Other Comprehensive Income (Loss)	(426)		2		512		(342)
Comprehensive Income (Loss)	(689)		36		(2,117)		(233)
Less: Comprehensive income (loss) attributable to noncontrolling interests	57		40		124		83
Comprehensive Income (Loss) Attributable to Hess Corporation	$	(746)	$	(4)	$	(2,241)	$	(316)

See accompanying Notes to Consolidated Financial Statements.

4

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED CASH FLOWS (UNAUDITED)

	Six Months Ended June 30,
	2020		2019
	(In millions)
Cash Flows From Operating Activities
Net income (loss)	$	(2,629)	$	109
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Gains) losses on asset sales, net	(8)		(22)
Depreciation, depletion and amortization	1,070		992
Impairment	2,126		—
Exploratory dry hole costs	135		—
Exploration lease and other impairment	38		11
Stock compensation expense	47		48
Noncash (gains) losses on commodity derivatives, net	119		58
Provision (benefit) for deferred income taxes and other tax accruals	(95)		(1)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	628		(70)
(Increase) decrease in inventories	(99)		(33)
Increase (decrease) in accounts payable and accrued liabilities	(520)		(130)
Increase (decrease) in taxes payable	(63)		14
Changes in other operating assets and liabilities	(38)		(63)
Net cash provided by (used in) operating activities	711		913
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(1,250)		(1,085)
Additions to property, plant and equipment - Midstream	(147)		(210)
Payments for Midstream equity investments	—		(23)
Proceeds from asset sales, net of cash sold	11		22
Other, net	(2)		(1)
Net cash provided by (used in) investing activities	(1,388)		(1,297)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	72		160
Debt with maturities of greater than 90 days:
Borrowings	1,000		—
Repayments	—		(5)
Payments on finance lease obligations	(3)		(45)
Common stock acquired and retired	—		(25)
Cash dividends paid	(157)		(164)
Noncontrolling interests, net	(128)		(27)
Other, net	(6)		4
Net cash provided by (used in) financing activities	778		(102)
Net Increase (Decrease) in Cash and Cash Equivalents	101		(486)
Cash and Cash Equivalents at Beginning of Year	1,545		2,694
Cash and Cash Equivalents at End of Period	$	1,646	$	2,208

See accompanying Notes to Consolidated Financial Statements.

5

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED EQUITY (UNAUDITED)

	Mandatory Convertible Preferred Stock		Common Stock		Capital in Excess of Par		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total Hess Stockholders' Equity		Noncontrolling Interests		Total Equity
	(In millions)
For the Three Months Ended June 30, 2020
Balance at April 1, 2020	$	—	$	307	$	5,633	$	1,021	$	239	$	7,200	$	978	$	8,178
Net income (loss)	—		—		—		(320)		—		(320)		57		(263)
Other comprehensive income (loss)	—		—		—		—		(426)		(426)		—		(426)
Share-based compensation	—		—		17		—		—		17		—		17
Dividends on common stock	—		—		—		(76)		—		(76)		—		(76)
Noncontrolling interests, net	—		—		—		—		—		—		(64)		(64)
Balance at June 30, 2020	$	—	$	307	$	5,650	$	625	$	(187)	$	6,395	$	971	$	7,366
For the Three Months Ended June 30, 2019
Balance at April 1, 2019	$	—	$	304	$	5,481	$	4,207	$	(650)	$	9,342	$	1,211	$	10,553
Net income (loss)	—		—		—		(6)		—		(6)		40		34
Other comprehensive income (loss)	—		—		—		—		2		2		—		2
Share-based compensation	—		—		32		—		—		32		—		32
Dividends on common stock	—		—		—		(76)		—		(76)		—		(76)
Noncontrolling interests, net	—		—		—		—		—		—		(14)		(14)
Balance at June 30, 2019	$	—	$	304	$	5,513	$	4,125	$	(648)	$	9,294	$	1,237	$	10,531
For the Six Months Ended June 30, 2020
Balance at January 1, 2020	$	—	$	305	$	5,591	$	3,535	$	(699)	$	8,732	$	974	$	9,706
Net income (loss)	—		—		—		(2,753)		—		(2,753)		124		(2,629)
Other comprehensive income (loss)	—		—		—		—		512		512		—		512
Share-based compensation	—		2		59		(5)		—		56		—		56
Dividends on common stock	—		—		—		(152)		—		(152)		—		(152)
Noncontrolling interests, net	—		—		—		—		—		—		(127)		(127)
Balance at June 30, 2020	$	—	$	307	$	5,650	$	625	$	(187)	$	6,395	$	971	$	7,366
For the Six Months Ended June 30, 2019
Balance at January 1, 2019	$	1	$	291	$	5,386	$	4,257	$	(306)	$	9,629	$	1,259	$	10,888
Net income (loss)	—		—		—		26		—		26		83		109
Other comprehensive income (loss)	—		—		—		—		(342)		(342)		—		(342)
Preferred stock conversion	(1)		12		(11)		—		—		—		—		—
Share-based compensation	—		1		60		—		—		61		—		61
Dividends on preferred stock	—		—		—		(4)		—		(4)		—		(4)
Dividends on common stock	—		—		—		(154)		—		(154)		—		(154)
Sale of water business to Hess Infrastructure Partners	—		—		78		—		—		78		(78)		—
Noncontrolling interests, net	—		—		—		—		—		—		(27)		(27)
Balance at June 30, 2019	$	—	$	304	$	5,513	$	4,125	$	(648)	$	9,294	$	1,237	$	10,531

See accompanying Notes to Consolidated Financial Statements.

6

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 June 30, 2020 and December 31, 2019, the consolidated results of operations for the three and six months ended June 30, 2020 and 2019, and consolidated cash flows for the six months ended June 30, 2020 and 2019.  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, 2019.

In the first quarter of 2020, we adopted 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 prior "incurred loss" model.  We calculate expected credit losses for our receivables using the probability of default and the expected loss given default.  Historical data, current market conditions, and forecasts of future economic conditions are used to determine the probability of default and the expected loss given default.  The adoption of this ASU did not have a material impact to our financial statements.

 2.  Inventories

Inventories consisted of the following:

	June 30, 2020		December 31, 2019
	(In millions)
Crude oil and natural gas liquids	$	204	$	92
Materials and supplies	156		169
Total Inventories	$	360	$	261

We have chartered three very large crude carriers (VLCCs) to load a total of approximately 6 million barrels of oil during May through August to sell in Asian markets later this year. During the second quarter, the Corporation loaded 3.7 million barrels of Bakken crude oil on VLCCs and included costs of the produced volumes totaling $113 million in crude oil inventories with a corresponding reduction to Marketing, including purchased oil and gas. In the first quarter of 2020, we recognized charges of $53 million ($52 million after income taxes) recorded in Marketing, including purchased oil and gas to reflect crude oil inventories at net realizable value.

3.  Property Plant and Equipment

Capitalized Exploratory Well Costs:  

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the six months ended June 30, 2020 (in millions):

Balance at January 1, 2020	$	584
Additions to capitalized exploratory well costs pending the determination of proved reserves	70
Capitalized exploratory well costs charged to expense	(125)
Balance at June 30, 2020	$	529

The table above does not include well costs incurred and expensed during the first six months of 2020 of $10 million associated with the Oldfield-1 well in the Gulf of Mexico. In the first quarter of 2020, the Corporation expensed previously capitalized well costs of $125 million, primarily related to the northern portion of the Shenzi Field (Hess 28%) in the Gulf of Mexico due to reprioritization of the Corporation’s forward capital program in response to the significant decline in crude oil prices.  Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $360 million at June 30, 2020 and primarily related to:  

Guyana: Approximately 80% of the capitalized well costs in excess of one year relate to successful exploration wells where hydrocarbons were encountered on the Stabroek Block (Hess 30%), offshore Guyana.  The operator plans further appraisal

7

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

drilling for certain fields and is conducting pre-development planning for additional phases of development beyond the two existing sanctioned phases of development.

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 ongoing commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block.

Malaysia:  Approximately 10% of the capitalized well costs in excess of one year relate to the North Malay Basin (Hess 50%), offshore Peninsular Malaysia, where hydrocarbons were encountered in five successful exploration wells.  Subsurface evaluation and pre-development studies for future phases of development are ongoing. 

4.  Hess Midstream LP

At June 30, 2020 Hess Midstream LP (Hess Midstream), a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling $1,972 million (December 31, 2019: $1,941 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream assets available to settle the obligations of Hess Midstream include cash and cash equivalents totaling $3 million (December 31, 2019: $3 million) and property, plant and equipment with a carrying value of $3,069 million (December 31, 2019: $3,010 million).

5.  Debt

In the first quarter of 2020, we entered into a $1.0 billion three year term loan agreement with a maturity date of March 16, 2023.  In the second quarter of 2020, we successfully syndicated the loan. Borrowings under the term loan generally bear interest at LIBOR plus an applicable margin of 2.25%. The applicable margin varies based on the credit rating of the Corporation’s senior, unsecured, non-credit enhanced long-term debt, and will increase by 0.25% on each anniversary of the term loan. The term loan agreement contains customary representations, warranties and covenants, including the same financial covenant as our revolving credit facility which limits the ratio of Total Consolidated Debt to Total Capitalization (as such terms are defined in the revolving credit facility and term loan agreements) of the Corporation and its consolidated subsidiaries to 65%, and customary events of default.  At June 30, 2020, Hess Corporation had borrowings of $1.0 billion under this term loan agreement and was in compliance with this financial covenant.

8

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

6.  Revenue

Revenue from contracts with customers on a disaggregated basis was as follows:

	Exploration and Production												Midstream		Eliminations		Total
	United States		Guyana		Malaysia & JDA		Denmark		Libya		E&P Total
	(In millions)
Three Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	254	$	31	$	1	$	14	$	—	$	300	$	—	$	—	$	300
Natural gas liquids revenue	43		—		—		—		—		43		—		—		43
Natural gas revenue	32		—		89		2		—		123		—		—		123
Sales of purchased oil and gas	143		—		—		—		—		143		—		—		143
Intercompany revenue	—		—		—		—		—		—		270		(270)		—
Total revenues from contracts with customers	472		31		90		16		—		609		270		(270)		609
Other operating revenues (a)	188		27		—		9		—		224		—		—		224
Total sales and other operating revenues	$	660	$	58	$	90	$	25	$	—	$	833	$	270	$	(270)	$	833
Three Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	762	$	—	$	24	$	51	$	130	$	967	$	—	$	—	$	967
Natural gas liquids revenue	48		—		—		—		—		48		—		—		48
Natural gas revenue	33		—		154		2		6		195		—		—		195
Sales of purchased oil and gas	439		—		—		—		22		461		—		—		461
Intercompany revenue	—		—		—		—		—		—		190		(190)		—
Total revenues from contracts with customers	1,282		—		178		53		158		1,671		190		(190)		1,671
Other operating revenues (a)	(11)		—		—		—		—		(11)		—		—		(11)
Total sales and other operating revenues	$	1,271	$	—	$	178	$	53	$	158	$	1,660	$	190	$	(190)	$	1,660
Six Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	919	$	69	$	3	$	50	$	—	$	1,041	$	—	$	—	$	1,041
Natural gas liquids revenue	91		—		—		—		—		91		—		—		91
Natural gas revenue	70		—		228		4		2		304		—		—		304
Sales of purchased oil and gas	459		1		—		—		—		460		—		—		460
Intercompany revenue	—		—		—		—		—		—		561		(561)		—
Total revenues from contracts with customers	1,539		70		231		54		2		1,896		561		(561)		1,896
Other operating revenues (a)	243		33		1		14		—		291		—		—		291
Total sales and other operating revenues	$	1,782	$	103	$	232	$	68	$	2	$	2,187	$	561	$	(561)	$	2,187
Six Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	1,444	$	—	$	45	$	67	$	221	$	1,777	$	—	$	—	$	1,777
Natural gas liquids revenue	116		—		—		—		—		116		—		—		116
Natural gas revenue	75		—		334		5		12		426		—		—		426
Sales of purchased oil and gas	865		—		—		—		44		909		—		—		909
Intercompany revenue	—		—		—		—		—		—		380		(380)		—
Total revenues from contracts with customers	2,500		—		379		72		277		3,228		380		(380)		3,228
Other operating revenues (a)	4		—		—		—		—		4		—		—		4
Total sales and other operating revenues	$	2,504	$	—	$	379	$	72	$	277	$	3,232	$	380	$	(380)	$	3,232

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

There have been no significant changes to contracts with customers or composition thereof during the six months ended June 30, 2020.  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.

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7.  Impairment

Oil and Gas Properties:

As a result of the significant decline in crude oil prices due to the global economic slowdown from the coronavirus (COVID-19) pandemic, we reviewed our oil and gas properties within the Exploration and Production operating segment for impairment in the first quarter of 2020.  We recognized pre-tax impairment charges in the first quarter of 2020 to reduce the carrying value of our oil and gas properties and certain related right-of-use assets at the North Malay Basin in Malaysia by $755 million ($755 million after income taxes), the South Arne Field in Denmark by $670 million ($594 million after income taxes), and in the Gulf of Mexico, the Stampede Field by $410 million ($410 million after income taxes) and the Tubular Bells Field by $270 million ($270 million after income taxes) primarily as a result of a lower long-term crude oil price outlook.  The impairment charges were based on estimates of fair value at March 31, 2020 determined by discounting internally developed future net cash flows, a Level 3 fair value measurement.  The total of the fair value estimates was approximately $1.05 billion.  Significant inputs used in determining the discounted future net cash flows include future prices, projected production volumes using risk adjusted oil and gas reserves, and discount rates.  The future pricing assumptions used were based on forward strip crude oil prices as of March 31, 2020 for the remainder of 2020 through 2022, and $50 per barrel for WTI ($55 per barrel for Brent) in 2023 and thereafter to the end of field life.  The weighted average crude oil benchmark price based on total projected crude oil volumes for the impaired assets was $48.82 per barrel.  A discount rate of 10% was used in each of the fair value measurements which represents the estimated discount rate a market participant would use.  We determined the discount rate by considering the weighted average cost of capital for a group of peer companies.

Other Assets:

In the first quarter of 2020, we recognized impairment charges totaling $21 million pre-tax ($20 million after income taxes) related to drilling rig right-of-use assets in the Bakken and surplus materials and supplies.

8. Retirement Plans

Components of net periodic pension cost consisted of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Service cost	$	14	$	11	$	28	$	21
Interest cost (a)	19		24		37		48
Expected return on plan assets (a)	(45)		(45)		(90)		(90)
Amortization of unrecognized net actuarial losses (a)	12		12		24		23
Pension (income) expense (a)	$	—	$	2	$	(1)	$	2

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three and six months ended June 30, 2020 was income of $14 million and $29 million, respectively, compared with income of $9 million and $19 million for the three and six months ended June 30, 2019, respectively.

To preserve cash in 2020, we are minimizing non-required cash contributions to funded pension plans.  In 2020, we expect to contribute approximately $2 million to our funded pension plans.

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9.  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 June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net income (loss)	$	(263)	$	34	$	(2,629)	$	109
Less: Net income (loss) attributable to noncontrolling interests	57		40		124		83
Less: Preferred stock dividends	—		—		—		4
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(320)	$	(6)	$	(2,753)	$	22
Weighted average number of common shares outstanding:
Basic	305.0		302.2		304.5		299.8
Effect of dilutive securities
Restricted common stock	—		—		—		0.9
Stock options	—		—		—		0.2
Performance share units	—		—		—		1.2
Diluted	305.0		302.2		304.5		302.1

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
Restricted common stock	2,173,061	2,156,525	2,094,360	28,970
Stock options	4,429,642	4,894,731	4,239,533	2,920,944
Performance share units	992,166	1,858,050	1,144,261	32,831
Common shares from conversion of preferred stock	—	—	—	1,954,473

During the six months ended June 30, 2020, we granted 1,120,356 shares of restricted stock (2019: 945,009), 307,999 performance share units (2019: 234,866) and 686,639 stock options (2019: 526,968).

10.  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

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groundwater in Maryland by introducing thereto gasoline with MTBE.  The suit filed in Maryland state court, was served on us in January 2018 and has been removed to Federal court by the defendants.

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

In March 2014, we received an Administrative Order from the EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York.  Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected shipbuilding and repair facility adjacent to the Canal.  The remedy selected by the EPA includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap.  The EPA’s original estimate was that this remedy would cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain.  We have complied with the EPA’s March 2014 Administrative Order and contributed funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert.  In January 2020, we received an additional Administrative Order from the EPA requiring us and several other parties to begin Remedial Action along the uppermost portion of the Canal.  We intend to comply with this Administrative Order.  The remediation work is anticipated to begin in the fourth quarter of 2020.  The costs will continue to be allocated amongst the parties, as they were for the Remedial Design.  

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

From time to time, we are involved in other judicial and administrative proceedings, including proceedings relating to other environmental matters.  We cannot predict with certainty if, how or when such proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages.  Numerous issues may need to be resolved, including through potentially lengthy discovery and determination of important factual matters before a loss or range of loss can be reasonably estimated for any proceeding.

Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of lawsuits, claims and proceedings, including the matters disclosed above, is not expected to have a material adverse effect on our financial condition, results of operations or cash flows.  However, we could incur judgments, enter into settlements, or revise our opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations in the period in which the amounts are accrued and our cash flows in the period in which the amounts are paid.

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11.  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 June 30, 2020
Sales and Other Operating Revenues - Third parties	$	833	$	—	$	—	$	—	$	833
Intersegment Revenues	—		270		—		(270)		—
Sales and Other Operating Revenues	$	833	$	270	$	—	$	(270)	$	833
Net Income (Loss) attributable to Hess Corporation	$	(249)	$	51	$	(122)	$	—	$	(320)
Depreciation, Depletion and Amortization	470		39		—		—		509
Provision (Benefit) for Income Taxes	(11)		2		—		—		(9)
Capital Expenditures	428		79		—		—		507
For the Three Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	1,660	$	—	$	—	$	—	$	1,660
Intersegment Revenues	—		190		—		(190)		—
Sales and Other Operating Revenues	$	1,660	$	190	$	—	$	(190)	$	1,660
Net Income (Loss) attributable to Hess Corporation	$	68	$	35	$	(109)	$	—	$	(6)
Depreciation, Depletion and Amortization	459		35		—		—		494
Provision (Benefit) for Income Taxes	131		—		1		—		132
Capital Expenditures	625		69		—		—		694
For the Six Months Ended June 30, 2020
Sales and Other Operating Revenues - Third parties	$	2,187	$	—	$	—	$	—	$	2,187
Intersegment Revenues	—		561		—		(561)		—
Sales and Other Operating Revenues	$	2,187	$	561	$	—	$	(561)	$	2,187
Net Income (Loss) attributable to Hess Corporation	$	(2,620)	$	112	$	(245)	$	—	$	(2,753)
Depreciation, Depletion and Amortization	991		77		2		—		1,070
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(88)		4		(4)		—		(88)
Capital Expenditures	1,037		136		—		—		1,173
For the Six Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	3,232	$	—	$	—	$	—	$	3,232
Intersegment Revenues	—		380		—		(380)		—
Sales and Other Operating Revenues	$	3,232	$	380	$	—	$	(380)	$	3,232
Net Income (Loss) attributable to Hess Corporation	$	177	$	72	$	(223)	$	—	$	26
Depreciation, Depletion and Amortization	923		69		—		—		992
Provision (Benefit) for Income Taxes	226		—		—		—		226
Capital Expenditures	1,140		196		—		—		1,336

Identifiable assets by operating segment were as follows:

	June 30, 2020		December 31, 2019
	(In millions)
Exploration and Production	$	14,267	$	16,790
Midstream	3,550		3,499
Corporate, Interest and Other	1,729		1,493
Total	$	19,546	$	21,782

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

12.  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 June 30, 2020, these forward contracts relate to the British Pound and the Danish Krone.  Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.

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

	June 30, 2020		December 31, 2019
	(In millions)
Commodity - crude oil put options (millions of barrels)	27.6		54.9
Foreign exchange forwards	$	74	$	90
Interest rate swaps	$	100	$	100

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

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

	Assets		Liabilities
	(In millions)
June 30, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	450	$	—
Interest rate swaps - Other assets (noncurrent)	6		—
Total derivative contracts designated as hedging instruments	456		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts receivable - Joint venture and other	2		—
Total derivative contracts not designated as hedging instruments	2		—
Gross fair value of derivative contracts	458		—
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	458	$	—
December 31, 2019
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	125	$	—
Interest rate swaps - Other assets (noncurrent)	1		—
Total derivative contracts designated as hedging instruments	126		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts payable	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	126		(1)
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	126	$	(1)

All fair values in the table above are based on Level 2 inputs.

Derivative contracts designated as hedging instruments:

Crude oil derivatives:  Crude oil hedging contracts increased Sales and other operating revenues by $228 million and $292 million in the three and six months ended June 30, 2020, respectively. In the three and six months ended June 30, 2019, the impact from crude oil hedging contracts on Sales and other operating revenues was a decrease of $14 million and an increase of $1 million, respectively. At June 30, 2020, pre-tax deferred gains in Accumulated other comprehensive income (loss) related to outstanding crude

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

oil price hedging contracts were $386 million which will be reclassified into earnings during the remainder of 2020 as the originally hedged crude oil sales are recognized in earnings.  

Interest rate swaps designated as fair value hedges:  At June 30, 2020 and December 31, 2019, we had interest rate swaps with gross notional amounts totaling $100 million, which were designated as fair value hedges and relate to debt where we have converted interest payments from fixed to floating rates.  Changes in the fair value of interest rate swaps and the hedged fixed-rate debt are recorded in Interest expense in the Statement of Consolidated Income.  In the three and six months ended June 30, 2020, the change in fair value of interest rate swaps was an increase in the asset of $1 million and $6 million, respectively, compared with a decrease in the liability of $2 million and $3 million in the three and six months ended June 30, 2019, 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 Revenues and non-operating income in the Statement of Consolidated Income were losses of $2 million and $3 million in the three and six months ended June 30, 2020, respectively, compared with losses of $2 million and gains of $3 million in the three and six months ended June 30, 2019, respectively.  A component of foreign exchange gains and losses is the result of foreign exchange derivative contracts that are not designated as hedges which amounted to net gains of $1 million and $3 million in the three and six months ended June 30, 2020, respectively, compared with net gains of $1 million and $1 million in the three and six months ended June 30, 2019, 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 June 30, 2020.  At June 30, 2020, total long-term debt, which was primarily comprised of fixed-rate debt instruments, had a carrying value of $8,210 million and a fair value of $8,736 million based on Level 2 inputs.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read together with the unaudited consolidated financial statements and accompanying footnotes for the quarter ended June 30, 2020 included under Item 1.  Financial Statements of this Form 10-Q and the audited consolidated financial statements and related notes included in Item 8 of our Annual Report on Form 10-K for the year ended December 31, 2019.  This discussion contains forward-looking statements that involve risks and uncertainties.  Our actual results could differ materially from those discussed below.  Factors that could cause or contribute to such differences include, but are not limited to, those identified below under the section entitled “Risk Factors” and those discussed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2019 and Part II, Item 1A. in our Form 10-Q for the fiscal quarter ended March 31, 2020.

Overview

Hess Corporation is a global Exploration and Production (E&P) company engaged in exploration, development, production, transportation, purchase and sale of crude oil, natural gas liquids (NGLs), and natural gas with production operations located primarily in the United States (U.S.), Guyana, the Malaysia/Thailand Joint Development Area (JDA), Malaysia, and Denmark. We conduct exploration activities primarily offshore Guyana, the U.S. Gulf of Mexico, and offshore Suriname and Canada.  At the Stabroek Block (Hess 30%), offshore Guyana, we have announced sixteen significant discoveries.  The Liza Phase 1 development achieved first production in December 2019, with peak production expected to reach 120,000 gross bopd in August.  The Liza Phase 2 development was sanctioned in the second quarter of 2019 and is expected to start up in early 2022 with production reaching 220,000 gross bopd.

Our Midstream operating segment, which is comprised of Hess Corporation’s 47% consolidated ownership interest in Hess Midstream LP, provides fee-based services, including gathering, compressing and processing natural gas and fractionating NGL; gathering, terminaling, loading and transporting crude oil and NGL; storing and terminaling propane, and water handling services primarily in the Bakken shale play in the Williston Basin area of North Dakota.

Hess Response to Global Pandemic and Market Conditions

The global COVID-19 pandemic continues to have a profound impact on society and industry. The Corporation’s first priority in the midst of the COVID-19 pandemic has been the health and safety of the Hess workforce and local communities. A multidisciplinary Hess emergency response team has been overseeing plans and precautions to reduce the risks of COVID-19 in the work environment while maintaining business continuity based on the most current recommendations by government and public health agencies. The Corporation has implemented a variety of health and safety measures including enhanced cleaning procedures and modified work practices such as travel restrictions, health screenings, reduced personnel at offshore platforms and onshore work sites wherever this can be done safely, and remote working arrangements for office workers. In July 2020, Hess Midstream LP announced that the planned maintenance turnaround at the Tioga Gas Plant originally scheduled for the third quarter of 2020 will be deferred until 2021 to ensure safe and timely execution in light of the COVID-19 pandemic.

In addition to the global health concerns of COVID-19, the pandemic has severely impacted demand for oil. In response to the resulting sharp decline in oil prices, the Corporation’s focus is on preserving cash and capability, while protecting the long-term value of its assets. In the first quarter of 2020, Hess entered into a new $1.0 billion three year term loan agreement and further reduced its E&P capital and exploratory budget for 2020 to $1.9 billion, a 37% reduction from the original budget of $3.0 billion. This reduction will be achieved primarily by shifting from a six-rig program to one rig in the Bakken, which was accomplished in May, and deferring discretionary spending across the portfolio, including reduced 2020 drilling activity on the Stabroek Block offshore Guyana and deferral of some development activities for the Payara Field pending government approval of the project, creating a potential delay in production startup of six to twelve months.

2020 Outlook

We project our E&P capital and exploratory expenditures will be approximately $1.9 billion in 2020. Oil and gas production in 2020, excluding Libya, is forecast to be approximately 330,000 boepd, up from previous guidance of 320,000 boepd. We have more than 80% of our forecasted crude oil production for the remainder of 2020 hedged with $55 WTI put options for 130,000 bopd and $60 Brent put options for 20,000 bopd. The fair value of the open crude oil put option contracts at June 30, 2020 was approximately $450 million. We also have no debt maturities until 2023 when the three year term loan matures.

Net cash provided by operating activities was $711 million in the first six months of 2020, compared with $913 million in the first six months of 2019.  Net cash provided by operating activities before changes in operating assets and liabilities was $803 million in the first six months of 2020 and $1,195 million in the first six months of 2019.  Capital expenditures were $1,173 million in the first six months of 2020 and $1,336 million in the first six months of 2019.

In 2020, based on current forward strip crude oil prices, we expect cash flow from operating activities, including settlements from crude oil put option contracts, cash and cash equivalents existing at June 30, 2020 of $1.6 billion, and our available committed revolving credit facility will be sufficient to fund our capital investment program and dividends. Due to the weak commodity price

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Overview (continued)

environment, we may take any of the following steps, or a combination thereof, to improve our liquidity and financial position: further reduce the planned capital program and other cash outlays, including dividends, pursue asset sales or issue debt or equity securities.

Second Quarter Results

In the second quarter of 2020, we incurred a net loss of $320 million, compared with a net loss of $6 million in the second quarter of 2019.  Excluding items affecting comparability of earnings between periods detailed on pages 24 and 25, we incurred an adjusted net loss of $28 million in the second quarter of 2019.  The decrease in second quarter 2020 results compared with adjusted results in the prior-year quarter, primarily reflects lower realized selling prices.

Exploration and Production Results

In the second quarter of 2020, E&P had a net loss of $249 million, compared with net income of $68 million in the second quarter of 2019.  Excluding items affecting comparability of earnings between periods, the adjusted net income for the second quarter of 2019 was $46 million.  Total net production, excluding Libya, averaged 334,000 boepd in the second quarter of 2020, compared with 273,000 boepd in the second quarter of 2019.  The average realized crude oil selling price, excluding the effect of hedging, was $20.63 per barrel in the second quarter of 2020, compared with $61.37 per barrel in the prior-year quarter reflecting a decrease in benchmark oil prices and widening of crude differentials realized as a result of reduced demand caused by the COVID-19 pandemic. In addition, a higher proportion of Bakken and Guyana production was sold in April and May which had lower prices than the month of June. Realized gains from crude oil hedging activities improved after-tax results by $228 million in the second quarter of 2020 and reduced after-tax results by $14 million in the second quarter of 2019. The average realized crude oil selling price, including hedging, was $38.46 per barrel, down from $60.45 per barrel in the second quarter of 2019.  The average realized NGLs selling price in the second quarter of 2020 was $7.32 per barrel, down from $12.18 per barrel in the prior-year quarter, while the average realized natural gas selling price was $2.41 per thousand cubic feet (mcf), down from $3.92 per mcf in the second quarter of 2019.

The following is an update of our ongoing E&P activities:

•In North Dakota, net production from the Bakken oil shale play averaged 194,000 boepd for the second quarter of 2020 (2019 Q2: 140,000 boepd), with net oil production up 26% to 108,000 bopd from 86,000 bopd in the year-ago period, primarily due to increased wells online and improved well performance. Natural gas and NGL production also increased from higher wells online, additional natural gas captured and processed at the Little Missouri 4 natural gas processing plant that commenced operations in July 2019, and additional volumes received under percentage of proceeds contracts resulting from lower prices. The Corporation reduced the number of rigs operating in the Bakken from six to one in May and drilled 17 wells, completed 31 wells, and brought 40 new wells online during the second quarter of 2020. We now forecast net production to average approximately 185,000 boepd for the third quarter and for the full year 2020 due to year to date performance and the deferral of the planned maintenance turnaround at the Tioga Gas Plant.

We have chartered three VLCCs to load a total of approximately 6 million barrels of oil during May through August to improve 2020 cash flow and enhance the value of our Bakken production. During the second quarter, we loaded 3.7 million barrels of crude oil on VLCCs and plan to load an additional 2.3 million barrels during the third quarter. The first VLCC cargo of 2 million barrels has been sold for delivery in China in September at a premium to Brent prices. The additional 4 million barrels of oil are expected to be sold in Asia in the fourth quarter of 2020.

We have committed capacity on Dakota Access Pipeline (DAPL) of approximately 55,000 bopd. On July 6, 2020, the United States District Court for the District of Columbia (District Court) ordered that the easement granted by the United States Army Corps of Engineers (Corps) for DAPL be vacated due to a failure of the Corps to produce an environmental impact statement and that DAPL be shut down and emptied of oil within 30 days. Dakota Access, LLC and the Corps are appealing the District Court’s decision on the merits to the United States Court of Appeals for the District of Columbia Circuit (Appeals Court) and requesting a stay of the District Court’s decision while the appeal is pending. On August 5, 2020, the Appeals Court stayed the District Court’s order insofar as it required that DAPL be shut down and emptied of oil, but declined to stay the portion of the order that vacated the easement granted by the Corps for DAPL. The partial stay of the District Court’s order will be in place until further proceedings are completed at the District Court and Appeals Court. If DAPL is ultimately required to shut in for any period of time, we expect to have capacity to move all of our Bakken production via alternative routes because of the flexibility provided by multiple takeaway alternatives, including rail and long term pipeline commitments, although the cost of moving any displaced DAPL barrels may increase by a few dollars per barrel.

17

PART I - FINANCIAL INFORMATION (CONT'D.)

Overview (continued)

•In the Gulf of Mexico, net production for the second quarter of 2020 averaged 68,000 boepd (2019 Q2: 65,000 boepd). The Esox-1 well, which commenced production in February, is expected to reach its gross peak rate of approximately 17,000 boepd, or 9,000 boepd net to Hess in the third quarter and is expected to average approximately 5,000 boepd net to Hess in 2020. The Corporation is participating in the BP operated Galapagos Deep exploration well (Hess 25%) which is a hub-class, Cretaceous-aged opportunity in the Mississippi Canyon area. The well spud in May and is still drilling.

•At the Stabroek Block (Hess 30%), offshore Guyana, net production from the Liza Phase 1 development averaged 22,000 bopd for the second quarter of 2020 following first production in December 2019. The operator, Esso Exploration and Production Guyana Limited, is currently commissioning water injection equipment and bringing natural gas injection fully online that should enable the Liza Destiny floating production, offloading and storage vessel (FPSO) to reach its capacity of 120,000 gross bopd in August. Phase 2 of the Liza Field development, which will utilize the Liza Unity FPSO with an expected capacity of 220,000 gross bopd, remains on target to achieve first oil in early 2022. As previously announced, some activities for a third development, Payara, with expected production capacity of 220,000 gross bopd, have been deferred pending government approval of the project creating a potential delay in production startup of six to twelve months.

As a result of COVID-19 related travel restrictions in Guyana, the operator temporarily idled two drillships but both drillships resumed drilling operations by the end of the second quarter. The Stena Carron rig recently completed appraisal drilling at Yellowtail-2, located 1 mile southeast of Yellowtail-1. The well identified two additional high quality reservoirs, one adjacent to, and the other below the Yellowtail field. The well results are being evaluated and are expected to help form the basis for a potential future development. The Noble Don Taylor commenced drilling of the Redtail exploration well, which is 1.25 miles northwest of Yellowtail-1, in July. The other two drillships, the Noble Bob Douglas and the Noble Tom Madden, are drilling and completing Liza Phase 1 and Phase 2 development wells.

•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged 23,000 boepd for the second quarter of 2020 (2019 Q2: 35,000 boepd), including contribution from unitized acreage in Malaysia, while net production from North Malay Basin, offshore Peninsular Malaysia, averaged 21,000 boepd for the second quarter of 2020 (2019 Q2: 24,000 boepd). Net production was lower at the JDA and North Malay Basin due to reduced natural gas nominations caused by COVID-19 impacts on economic activity.

•At the Waha fields (Hess 8%), onshore Libya, production ceased following the declaration of force majeure in January by the Libyan National Oil Corporation as a result of civil unrest.  Net production averaged 20,000 boepd for the second quarter of 2019.

Consolidated Results of Operations

The after-tax income (loss) by major operating activity is summarized below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation:
Exploration and Production	$	(249)	$	68	$	(2,620)	$	177
Midstream	51		35		112		72
Corporate, Interest and Other	(122)		(109)		(245)		(223)
Total	$	(320)	$	(6)	$	(2,753)	$	26
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic (a)	$	(1.05)	$	(0.02)	$	(9.04)	$	0.07
Diluted (b)	$	(1.05)	$	(0.02)	$	(9.04)	$	0.07

(a)Calculated as net income (loss) attributable to Hess Corporation less preferred stock dividends, divided by weighted average number of basic shares.

(b)Calculated as net income (loss) attributable to Hess Corporation less preferred stock dividends, divided by weighted average number of diluted shares.

18

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Items Affecting Comparability of Earnings Between Periods

The following table summarizes, on an after-tax basis, items of income (expense) that are included in net income (loss) and affect comparability of earnings between periods: 

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Items Affecting Comparability of Earnings Between Periods, After-Tax:
Exploration and Production	$	—	$	22	$	(2,251)	$	22
Midstream	—		—		—		—
Corporate, Interest and Other	—		—		—		—
Total	$	—	$	22	$	(2,251)	$	22

The items in the table above are explained on pages 24 and 25.

Reconciliations of GAAP and non-GAAP measures

The following table reconciles reported net income (loss) attributable to Hess Corporation and adjusted net income (loss) attributable to Hess Corporation:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Adjusted Net Income (Loss) Attributable to Hess Corporation:
Net income (loss) attributable to Hess Corporation	$	(320)	$	(6)	$	(2,753)	$	26
Less: Total items affecting comparability of earnings between periods, after-tax	—		22		(2,251)		22
Adjusted Net Income (Loss) Attributable to Hess Corporation	$	(320)	$	(28)	$	(502)	$	4

The following table reconciles reported net cash provided by (used in) operating activities and cash provided by (used in) operating activities before changes in operating assets and liabilities:

	Six Months Ended June 30,
	2020		2019
	(In millions)
Net cash provided by operating activities before changes in operating assets and liabilities:
Net cash provided by (used in) operating activities	$	711	$	913
Changes in operating assets and liabilities	92		282
Net cash provided by (used in) operating activities before changes in operating assets and liabilities	$	803	$	1,195

Adjusted net income (loss) attributable to Hess Corporation is a non-GAAP financial measure, which we define as reported net income (loss) attributable to Hess Corporation excluding items identified as affecting comparability of earnings between periods, which are summarized on pages 24 and 25.  Management uses adjusted net income (loss) to evaluate the Corporation’s operating performance and believes that investors’ understanding of our performance is enhanced by disclosing this measure, which excludes certain items that management believes are not directly related to ongoing operations and are not indicative of future business trends and operations.  

Net cash provided by (used in) operating activities before changes in operating assets and liabilities presented in this report is a non-GAAP measure, which we define as reported net cash provided by (used in) operating activities excluding changes in operating assets and liabilities.  Management uses net cash provided by (used in) operating activities before changes in operating assets and liabilities to evaluate the Corporation’s ability to internally fund capital expenditures, pay dividends and service debt and believes that investors’ understanding of our ability to generate cash to fund these items is enhanced by disclosing this measure, which excludes working capital and other movements that may distort assessment of our performance between periods.  

These measures are not, and should not be viewed as, substitutes for U.S. GAAP net income (loss) and net cash provided by (used in) operating activities.

19

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

In the following discussion and elsewhere in this report, the financial effects of certain transactions are disclosed on an after-tax basis.  Management reviews segment earnings on an after-tax basis and uses after-tax amounts in its review of variances in segment earnings.  Management believes that after-tax amounts are a preferable method of explaining variances in earnings, since they show the entire effect of a transaction rather than only the pre-tax amount.  After-tax amounts are determined by applying the income tax rate in each tax jurisdiction to pre-tax amounts.

Comparison of Results

Exploration and Production

Following is a summarized income statement of our E&P operations:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Revenues and Non-Operating Income
Sales and other operating revenues	$	833	$	1,660	$	2,187	$	3,232
Gains on asset sales, net	—		22		—		22
Other, net	(1)		7		7		27
Total revenues and non-operating income	832		1,689		2,194		3,281
Costs and Expenses
Marketing, including purchased oil and gas	97		498		522		932
Operating costs and expenses	203		231		417		444
Production and severance taxes	16		46		58		85
Midstream tariffs	225		165		466		327
Exploration expenses, including dry holes and lease impairment	31		43		220		77
General and administrative expenses	50		48		102		90
Depreciation, depletion and amortization	470		459		991		923
Impairment	—		—		2,126		—
Total costs and expenses	1,092		1,490		4,902		2,878
Results of Operations Before Income Taxes	(260)		199		(2,708)		403
Provision (benefit) for income taxes	(11)		131		(88)		226
Net Income (Loss) Attributable to Hess Corporation	$	(249)	$	68	$	(2,620)	$	177

Excluding the E&P items affecting comparability of earnings between periods detailed on pages 24 and 25, the changes in E&P results are primarily attributable to changes in selling prices, production and sales volumes, marketing expenses, cash operating costs, Midstream tariffs, depreciation, depletion and amortization (DD&A), exploration expenses and income taxes, as discussed below.

20

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Selling Prices:  Lower realized selling prices in the second quarter and first six months of 2020, decreased after-tax results by approximately $285 million and $520 million, respectively, compared to the same periods in 2019.  Average selling prices were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
Average Selling Prices (a)
Crude Oil – Per Barrel (Including Hedging)
United States
Onshore	$	38.23	$	56.08	$	42.26	$	54.14
Offshore	39.10		62.23		44.49		60.73
Total United States	38.57		58.22		43.03		56.49
Guyana	35.28		—		38.41		—
Malaysia and JDA	15.62		66.88		26.73		63.11
Denmark	50.29		70.27		53.49		69.51
Libya	—		69.87		—		66.72
Worldwide	38.46		60.45		42.98		58.25
Crude Oil – Per Barrel (Excluding Hedging)
United States
Onshore	$	18.93	$	57.19	$	32.52	$	54.09
Offshore	22.78		63.42		34.61		60.68
Total United States	20.48		59.36		33.23		56.43
Guyana	19.23		—		26.11		—
Malaysia and JDA	15.62		66.88		26.73		63.11
Denmark	29.16		70.27		41.19		69.51
Libya	—		69.87		—		66.72
Worldwide	20.63		61.37		32.90		58.20
Natural Gas Liquids – Per Barrel
United States
Onshore	$	7.59	$	12.16	$	8.39	$	15.22
Offshore	4.71		12.32		7.23		14.97
Worldwide	7.32		12.18		8.27		15.19
Natural Gas – Per Mcf
United States
Onshore	$	0.94	$	1.41	$	1.10	$	1.86
Offshore	1.14		2.19		1.23		2.37
Total United States	1.01		1.76		1.15		2.11
Malaysia and JDA	3.97		5.08		4.39		5.19
Denmark	3.51		3.74		3.63		3.89
Libya	—		5.78		4.90		5.44
Worldwide	2.41		3.92		2.81		4.18

(a)Selling prices in the United States are adjusted for certain processing and distribution fees included in Marketing expenses.  Excluding these fees Worldwide selling prices for the second quarter of 2020 would be $41.33 (Q2 2019: $63.33) per barrel for crude oil (including hedging), $23.50 (Q2 2019: $64.25) per barrel for crude oil (excluding hedging), $7.49 (Q2 2019: $12.38) per barrel for NGLs and $2.55 (Q2 2019: $3.99) per mcf for natural gas. Excluding these fees Worldwide selling prices for the first six months of 2020 would be $46.20 (2019: $61.32) per barrel for crude oil (including hedging), $36.12 (2019: $61.27) per barrel for crude oil (excluding hedging), $8.46 (2019: $15.37) per barrel for NGLs and $2.93 (2019: $4.25) per mcf for natural gas.

Crude oil hedging activities were a net gain of $228 million and $292 million before and after income taxes in the second quarter and first six months of 2020, respectively, and a net loss of $14 million and a net gain of $1 million before and after income taxes in the second quarter and first six months of 2019, respectively.  For calendar year 2020, we have WTI put options with an average monthly floor price of $55 per barrel for 130,000 bopd, and Brent put options with an average monthly floor price of $60 per barrel for 20,000 bopd.  At June 30, 2020, the fair value of the open crude oil put option contracts was approximately $450 million.  We expect noncash put option premium amortization, which will be reflected in realized selling prices, to reduce our third quarter results by approximately $70 million and reduce our full year 2020 results by approximately $280 million, which is unchanged from our previous full-year guidance.

21

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Production Volumes:  Our daily worldwide net production was as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In thousands)
Crude Oil – Barrels
United States
North Dakota (a)	108		87		111		86
Offshore	45		46		47		47
Total United States	153		133		158		133
Guyana	22		—		18		—
Malaysia and JDA	3		4		3		4
Denmark	5		6		6		6
Libya	—		18		2		19
Total	183		161		187		162
Natural Gas Liquids – Barrels
United States
North Dakota (a)	57		38		53		36
Offshore	6		5		6		6
Total United States	63		43		59		42
Natural Gas – Mcf
United States
North Dakota (a)	177		103		170		91
Offshore	101		83		107		88
Total United States	278		186		277		179
Malaysia and JDA	245		332		285		355
Denmark	5		6		6		6
Libya	—		11		3		12
Total	528		535		571		552
Barrels of Oil Equivalent (b)	334		293		341		296
Crude oil and natural gas liquids as a share of total production	74	%	70	%	72	%	69	%

(a)Net production from the Bakken was 194,000 boepd and 192,000 boepd in the second quarter and first six months of 2020, respectively, compared with 140,000 boepd and 135,000 boepd in the second quarter and first six months of 2019, respectively.

(b)Reflects natural gas production converted based on relative energy content (six mcf equals one barrel).  Barrel of oil equivalence does not necessarily result in price equivalence as the equivalent price of natural gas on a barrel of oil equivalent basis has been substantially lower than the corresponding price for crude oil over the recent past.  In addition, NGLs do not sell at prices equivalent to crude oil.  See the average selling prices in the table on page 21.

We forecast net production, excluding Libya, to be in the range of 320,000 boepd to 325,000 boepd for the third quarter and approximately 330,000 boepd for the full year of 2020.

United States:  North Dakota net oil production was higher in the second quarter and first six months of 2020, compared to the corresponding periods in 2019, primarily due to increased wells online and improved well performance.  North Dakota net natural gas and NGLs production was higher in the second quarter and first six months of 2020, compared to the corresponding periods in 2019, also due to higher wells online, additional natural gas captured and processed at the Little Missouri 4 natural gas processing plant that commenced operations in July 2019, and additional volumes received under percentage of proceeds contracts resulting from lower prices.  Total offshore net production in the second quarter and first six months of 2020 was comparable to the corresponding periods in 2019.

International:  Net production at Guyana was higher in the second quarter and first six months of 2020, compared to the corresponding periods in 2019, due to commencement of production from the Liza Phase 1 development in December 2019.  Net production at Libya was lower due to the cessation of production following the declaration of force majeure in January by the Libyan National Oil Corporation as a result of civil unrest.  Net production was lower at Malaysia and JDA due to reduced natural gas nominations caused by COVID-19 impacts on economic activity.

22

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Sales Volumes:  The impact of lower sales volumes decreased after-tax results by approximately $10 million in the second quarter of 2020, compared to corresponding period in 2019. The impact of higher sales volumes improved after-tax results by $175 million in the first six months of 2020, compared to the corresponding period in 2019.  Worldwide sales volumes from Hess net production, which excludes sales volumes of crude oil, NGLs and natural gas purchased from third parties, were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
	(In thousands)
Crude oil – barrels (a)	12,764	15,061	28,816	29,001
Natural gas liquids – barrels	5,690	3,931	10,787	7,562
Natural gas – mcf	48,081	48,638	103,701	100,073
Barrels of Oil Equivalent (b)	26,468	27,098	56,887	53,242
Crude oil – barrels per day (a)	140	166	158	160
Natural gas liquids – barrels per day	63	43	59	42
Natural gas – mcf per day	528	535	571	552
Barrels of Oil Equivalent Per Day (b)	291	298	312	294

(a)During the second quarter of 2020, 3.7 million barrels of crude oil were loaded on VLCCs for sale later in the year.

(b)Reflects natural gas production converted based on relative energy content (six mcf equals one barrel).  Barrel of oil equivalence does not necessarily result in price equivalence as the equivalent price of natural gas on a barrel of oil equivalent basis has been substantially lower than the corresponding price for crude oil over the recent past.  In addition, NGLs do not sell at prices equivalent to crude oil.  See the average selling prices in the table on page 21.

Marketing, including purchased oil and gas:  Marketing expense is mainly comprised of costs to purchase crude oil, NGL and natural gas from our partners in Hess operated wells or other third parties, primarily in the U.S., and transportation and other distribution costs for U.S. marketing activities.  Marketing expense was lower in the second quarter and first six months of 2020, compared with the corresponding periods in 2019, primarily due to lower benchmark crude oil prices on purchased volumes and a reduction of $113 million for the cost of crude oil inventory capitalized for the 3.7 million barrels of crude oil loaded on the VLCCs in the second quarter. In the first quarter of 2020, we incurred a pre-tax charge of $53 million to reflect crude oil inventory at its net realizable value at March 31, 2020 (see Items Affecting Comparability of Earnings Between Periods below).

Cash Operating Costs:  Cash operating costs consist of operating costs and expenses, production and severance taxes and E&P general and administrative expenses.  Cash operating costs decreased in the second quarter and first six months of 2020, compared with the corresponding periods in 2019, from lower production and severances taxes associated with lower crude oil prices and the impact of cost reduction initiatives. Per-unit costs were down in the second quarter and first six months of 2020 on the lower costs and the impact of higher production volumes.

Midstream Tariffs Expense:  Tariffs expense increased in the second quarter and first six months of 2020, compared with the corresponding periods in 2019, primarily due to higher throughput volumes in 2020.  We estimate Midstream tariffs expense to be in the range of $220 million to $230 million in the third quarter and in the range of $905 million to $930 million for the full year 2020.

DD&A:  DD&A expenses were higher in the second quarter and first six months of 2020, compared with the corresponding periods in 2019, reflecting higher production volumes. DD&A expense on a per-unit basis was lower in the second quarter and first six months of 2020, compared with the corresponding periods in 2019, primarily due to the year-over-year mix of production and as a result of the impairment charges in the first quarter of 2020.

Unit Costs:  Unit cost per barrel of oil equivalent (boe) information is based on total net production volumes.  Actual and forecast unit costs per boe are as follows:

	Actual								Forecast range (a)
	Three months ended June 30,				Six months ended June 30,				Three Months Ended September 30,	Twelve Months Ended December 31,
	2020		2019		2020		2019		2020	2020
Cash operating costs (b)	$	8.81	$	12.11	$	9.26	$	11.55	$10.00 — $10.50	$9.50 — $10.00
DD&A (c)	15.45		17.20		15.95		17.23		16.00 — 17.00	16.00 — 17.00
Total Production Unit Costs	$	24.26	$	29.31	$	25.21	$	28.78	$26.00 — $27.50	$25.50 — $27.00

(a)Forecast information excludes any contribution from Libya.

(b)Cash operating costs per boe, excluding Libya, were $8.64 and $9.13 in the three and six months ended June 30, 2020, respectively, compared with $12.72 and $12.12 in the same periods of 2019, respectively.

(c)DD&A per boe, excluding Libya, was $15.45 and $16.05 in the three and six months ended June 30, 2020, respectively, compared with $18.31 and $18.34 in the same periods of 2019, respectively.

23

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Exploration Expenses:  Exploration expenses were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Exploratory dry hole costs (a)	$	—	$	—	$	135	$	—
Exploration lease and other impairment (b)	6		4		38		11
Geological and geophysical expense and exploration overhead	25		39		47		66
Total Exploration Expense	$	31	$	43	$	220	$	77

(a)First six months of 2020 primarily relates to previously capitalized exploratory wells (see Items Affecting Comparability of Earnings Between Periods below) and the Oldfield-1 exploration well in the Gulf of Mexico.

(b)First six months of 2020 includes impaired leasehold costs due to a reprioritization of the Corporation’s forward capital program.

Exploration expenses, excluding dry hole expense, are estimated to be in the range of $35 million to $40 million in the third quarter of 2020 and $140 million to $150 million for the full year of 2020.

Income Taxes:  The decline in income tax expense in the second quarter and first six months of 2020, compared to the corresponding periods in 2019, is primarily due to lower pre-tax income in Libya as a result of the declaration of force majeure in January 2020.  Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense in the second quarter and first six months of 2020 was a benefit of $3 million and an expense of $6 million, respectively, compared with an expense of $7 million and $9 million in the second quarter and first six months of 2019, respectively.  Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense is expected to be an expense in the range of $10 million to $15 million for the third quarter of 2020 and $20 million to $30 million for the full year of 2020.

Items Affecting Comparability of Earnings Between Periods:

The following table summarizes, on an after-tax basis, income (expense) items affecting comparability of E&P earnings between periods:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Impairment	$	—	$	—	$	(2,049)	$	—
Dry hole, lease impairment and other exploration expenses	—		—		(150)		—
Crude oil inventories write-down	—		—		(52)		—
Gain on asset sale, net	—		22		—		22
	$	—	$	22	$	(2,251)	$	22

The following table summarizes, on a pre-tax basis, income (expense) items affecting comparability of E&P earnings between periods:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Impairment	$	—	$	—	$	(2,126)	$	—
Dry hole, lease impairment and other exploration expenses	—		—		(152)		—
Crude oil inventories write-down	—		—		(53)		—
Gain on asset sale, net	—		22		—		22
	$	—	$	22	$	(2,331)	$	22

Impairment: In the first quarter of 2020, we recorded noncash impairment charges totaling $2.1 billion ($2.0 billion after income taxes) related to our oil and gas properties at North Malay Basin in Malaysia, the South Arne Field in Denmark, and the Stampede Field and the Tubular Bells Field in the Gulf of Mexico, primarily as a result of a lower long-term crude oil price outlook. Other charges totaling $21 million pre-tax ($20 million after income taxes) related to drilling rig right-of-use assets in the Bakken and surplus materials and supplies. See Note 7, Impairment in the Notes to Consolidated Financial Statements.

Dry hole, lease impairment and other exploration expenses: In the first quarter of 2020, we incurred pre-tax charges totaling $152 million ($150 million after income taxes), primarily related to the write-off of previously capitalized exploratory wells in the Gulf of Mexico as detailed in Note 3, Property, plant and equipment in the Notes to Consolidated Financial Statements, and to impair certain exploration leasehold costs.

24

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Crude oil inventories write-down: In the first quarter of 2020, we incurred a pre-tax charge of $53 million ($52 million after income taxes) to reduce crude oil inventories to their net realizable value. These charges are included in Marketing, including purchased oil and gas in the Statement of Consolidated Income. See Note 2, Inventories in the Notes to Consolidated Financial Statements.

Gain on asset sale, net:  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.

Midstream

Following is a summarized income statement for our Midstream operations:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Revenues and Non-Operating Income
Sales and other operating revenues	$	270	$	190	$	561	$	380
Other, net	1		—		3		—
Total revenues and non-operating income	271		190		564		380
Costs and Expenses
Operating costs and expenses	95		58		187		113
General and administrative expenses	4		5		12		11
Depreciation, depletion and amortization	39		35		77		69
Interest expense	23		17		48		32
Total costs and expenses	161		115		324		225
Results of Operations Before Income Taxes	110		75		240		155
Provision (benefit) for income taxes	2		—		4		—
Net Income (Loss)	108		75		236		155
Less: Net income (loss) attributable to noncontrolling interests	57		40		124		83
Net Income (Loss) Attributable to Hess Corporation	$	51	$	35	$	112	$	72

Sales and other operating revenues for the second quarter and first six months of 2020 increased, compared to the corresponding periods in 2019, primarily due to higher throughput volumes and increased rail transportation revenues associated with third-party services.  Operating costs and expenses for the second quarter and first six months of 2020 increased, compared to the corresponding periods in 2019, primarily due to increased third-party rail transportation charges, maintenance expenditures on expanded infrastructure and initial costs related to the Tioga Gas Plant turnaround.

The increase in interest expense from 2019 reflects higher borrowings by the Midstream business.

Excluding items affecting comparability of earnings, net income attributable to Hess Corporation from the Midstream segment is estimated to be in the range of $40 million to $50 million in the third quarter of 2020 and in the range of $195 million to $205 million for the full year of 2020.

Corporate, Interest and Other

The following table summarizes Corporate, Interest and Other expenses:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Corporate and other expenses (excluding items affecting comparability)	$	26	$	28	$	65	$	60
Interest expense	96		89		184		179
Less: Capitalized interest	—		(9)		—		(16)
Interest expense, net	96		80		184		163
Corporate, Interest and Other expenses before income taxes	122		108		249		223
Provision (benefit) for income taxes	—		1		(4)		—
Net Corporate, Interest and Other expenses after income taxes	$	122	$	109	$	245	$	223

25

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Corporate and other expenses were higher in the first six months of 2020, compared to the corresponding period in 2019, primarily due to a charge of $7 million for legal costs related to former downstream businesses.  Interest expense, net was higher in the second quarter and first six months of 2020, compared to the corresponding periods in 2019, due to the cessation of capitalized interest at the Liza Field, offshore Guyana, upon commencement of production in December 2019, and due to interest on a new $1.0 billion three year term loan entered into in the first quarter of 2020.

Third quarter 2020 corporate expenses are expected to be in the range of $25 million to $30 million, and interest expense is expected to be in the range of $95 million to $100 million.  We estimate corporate expenses for full year 2020 to be in the range of $115 million to $125 million, and interest expense to be in the range of $375 million to $380 million.  

Other Items Potentially Affecting Future Results

Our future results may be impacted by a variety of factors, including but not limited to, volatility in the selling prices of crude oil, NGLs and natural gas, reserve and production changes, asset sales, impairment charges and exploration expenses, industry cost inflation and/or deflation, changes in foreign exchange rates and income tax rates, changes in deferred tax asset valuation allowances, the effects of weather, crude oil storage capacity, political risk, environmental risk and catastrophic risk, including risks associated with COVID-19.  For a more comprehensive description of the risks that may affect our business, see the section entitled Item 1A. Risk Factors in this Quarterly Report on Form 10-Q, in Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019 and Part II, Item 1A. Risk Factors in our Form 10-Q for the fiscal quarter ended March 31, 2020.

Proved reserves are calculated using the average price during the twelve month period before December 31 determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within the year, unless prices are defined by contractual agreements, excluding escalations based on future conditions.  Crude oil prices used in the determination of proved reserves at December 31, 2019 were $55.73 per barrel for WTI and $62.54 per barrel for Brent, which are significantly higher than the average crude oil benchmark prices for the six months ended June 30, 2020 (WTI - $36.82 per barrel; Brent - $42.10 per barrel).  If crude oil prices for the rest of 2020 remain significantly below prices used for proved reserves at December 31, 2019, proved reserves at December 31, 2020 are expected to be significantly lower than proved reserves at December 31, 2019.  It is difficult to estimate the magnitude of any net negative change in proved reserves that may result from lower crude oil prices due to a number of factors that are currently unknown, including 2020 crude oil prices, any revisions in proved reserves that may occur based on 2020 reservoir performance, the levels to which industry costs will decline in response to lower prices, and management’s plans as of December 31, 2020 for developing proved undeveloped reserves.  Any reductions to proved reserves will increase depreciation, depletion and amortization expense and reduce the Standardized Measure of Discounted Future Net Cash Flows.

Liquidity and Capital Resources

The following table sets forth certain relevant measures of our liquidity and capital resources:

	June 30, 2020			December 31, 2019
	(In millions, except ratio)
Cash and cash equivalents (a)	$	1,646		$	1,545
Current maturities of long-term debt	5			—
Total debt (b)	8,210			7,142
Total equity	7,366			9,706
Debt to capitalization ratio (c)	44.3		%	39.6		%

(a)Includes $3 million of cash attributable to our Midstream segment, at June 30, 2020 (December 31, 2019: $3 million).

(b)At June 30, 2020, includes $1,828 million of debt outstanding from our Midstream segment (December 31, 2019: $1,753 million) that is non-recourse to Hess Corporation.

(c)The debt of Hess Corporation (excluding Midstream non-recourse debt) as a percentage of the sum of debt plus equity (excluding the impact of noncash impairment charges and non-controlling interests) as defined under Hess Corporation’s revolving credit facility and term loan debt covenants.

26

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

Cash Flows

The following table summarizes our cash flows:

	Six Months Ended June 30,
	2020		2019
	(In millions)
Net cash provided by (used in):
Operating activities	$	711	$	913
Investing activities	(1,388)		(1,297)
Financing activities	778		(102)
Net Increase (Decrease) in Cash and Cash Equivalents	$	101	$	(486)

Operating activities:  Net cash provided by operating activities was $711 million in the first six months of 2020, compared to $913 million in the first six months of 2019.  Changes in operating assets and liabilities was a use of cash of $92 million in the first six months of 2020, and a use of cash of $282 million in the first six months of 2019. Changes in operating assets and liabilities in 2019 included a one-time payment of approximately $130 million to our joint venture partner for its share of sale/leaseback proceeds related to our sale of the North Malay Basin floating storage and offloading vessel that we received in 2018.

Investing activities:  Additions to property, plant and equipment of $1,397 million in the first six months of 2020 were up $102 million compared with the corresponding period in 2019.  The increase primarily reflects payments in the first quarter of 2020 to settle capital expenditures accrued in the fourth quarter of 2019, partially offset by lower overall activity across the portfolio.  The first six months of 2019 included additions of approximately $90 million associated with the Midstream operating segment's acquisition of assets from Summit Midstream Partners LP.

The following table reconciles capital expenditures incurred on an accrual basis to Additions to property, plant and equipment:

	Six Months Ended June 30,
	2020		2019
	(In millions)
Additions to property, plant and equipment - E&P:
Capital expenditures incurred - E&P	$	(1,037)	$	(1,140)
Increase (decrease) in related liabilities	(213)		55
Additions to property, plant and equipment - E&P	$	(1,250)	$	(1,085)
Additions to property, plant and equipment - Midstream:
Capital expenditures incurred - Midstream	$	(136)	$	(196)
Increase (decrease) in related liabilities	(11)		(14)
Additions to property, plant and equipment - Midstream	$	(147)	$	(210)

 Financing activities: Borrowings in the first six months of 2020 include $1.0 billion related to our new three year term loan.  Hess Midstream borrowed a total of $72 million from their revolving credit facilities in the first six months of 2020 and $160 million in the first six months of 2019.  We paid common stock dividends totaling $157 million in the first six months of 2020, compared to common stock and preferred dividends of $164 million in the first six months of 2019.  In addition, net cash outflows to noncontrolling interests were $128 million in the first six months of 2020 and $27 million in the first six months of 2019.

Future Capital Requirements and Resources

At June 30, 2020, we had $1.6 billion in cash and cash equivalents, excluding Midstream, and total liquidity, including available committed credit facilities, of approximately $5.3 billion.  Our fully undrawn $3.5 billion committed revolving credit facility matures in May 2023, and we have no debt maturities until 2023 when the three year term loan matures.  Oil and gas production in 2020, excluding Libya, is forecast to be approximately 330,000 boepd.  We have more than 80% of our forecasted crude oil production for the remainder of 2020 hedged with $55 WTI put options for 130,000 bopd and $60 Brent put options for 20,000 bopd. The fair value of the open crude oil put option contracts at June 30, 2020 was approximately $450 million.

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PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)  

Net cash provided by operating activities was $711 million in the first six months of 2020, compared with $913 million in the first six months of 2019.  Net cash provided by operating activities before changes in operating assets and liabilities was $803 million in the first six months of 2020 and $1,195 million in the first six months of 2019.  Capital expenditures were $1,173 million in the first six months of 2020 and $1,336 million in the first six months of 2019.  In 2020, based on current forward strip crude oil prices, we expect cash flow from operating activities, including settlements from crude oil put option contracts, cash and cash equivalents existing at June 30, 2020, and our available committed revolving credit facility will be sufficient to fund our capital investment program and dividends. Due to the weak commodity price environment, we may take any of the following steps, or a combination thereof, to improve our liquidity and financial position: further reduce the planned capital program and other cash outlays, including dividends, pursue asset sales or issue debt or equity securities.

The table below summarizes the capacity, usage, and available capacity for borrowings and letters of credit under committed and uncommitted credit facilities at June 30, 2020:

	Expiration Date	Capacity		Borrowings		Letters of Credit Issued		Total Used		Available Capacity
		(In millions)
Hess Corporation
Revolving credit facility	May, 2023	$	3,500	$	—	$	—	$	—	$	3,500
Committed lines	Various (a)	175		—		54		54		121
Uncommitted lines	Various (a)	207		—		207		207		—
Total - Hess Corporation		$	3,882	$	—	$	261	$	261	$	3,621
Midstream
Revolving credit facility (b)	December, 2024	$	1,000	$	104	$	—	$	104	$	896
Total - Midstream		$	1,000	$	104	$	—	$	104	$	896

(a)Committed and uncommitted lines have expiration dates through 2020.

(b)This credit facility may only be utilized by HESM Opco and is non-recourse to Hess Corporation.

Hess Corporation:

In the first quarter of 2020, we entered into a $1.0 billion three year term loan agreement with a maturity date of March 16, 2023. In the second quarter of 2020, we successfully syndicated the loan.  Borrowings under the term loan generally bear interest at LIBOR plus an applicable margin of 2.25%. The applicable margin varies based on the credit rating of the Corporation’s senior, unsecured, non-credit enhanced long-term debt, and will increase by 0.25% on each anniversary of the term loan. The term loan agreement contains customary representations, warranties and covenants, including the same financial covenant as our revolving credit facility which limits the ratio of Total Consolidated Debt to Total Capitalization (as such terms are defined in the revolving credit facility and term loan agreements) of the Corporation and its consolidated subsidiaries to 65%, and customary events of default.  At June 30, 2020, Hess Corporation had borrowings of $1.0 billion under this term loan agreement and was in compliance with this financial covenant.

At June 30, 2020, Hess Corporation had no outstanding borrowings or letters of credit under its revolving credit facility and was in compliance with its financial covenants.

Two of the three major credit rating agencies that rate our debt have assigned an investment grade rating.  In March 2020, Standard and Poor’s Ratings Services affirmed our credit rating at BBB- and revised the outlook to negative (from stable) while Fitch Ratings assigned a BBB- rating to the $1.0 billion term loan, with no change to our BBB- credit rating and stable outlook.  In March 2020, Moody’s Investors Service affirmed our credit rating at Ba1 with stable outlook, which is below investment grade.  

We have a shelf registration under which we may issue additional debt securities, warrants, common stock or preferred stock.

Midstream:

At June 30, 2020, Hess Midstream Operations LP (formerly Hess Midstream Partners LP, or HESM Opco), a consolidated subsidiary of Hess Midstream LP, had $1.4 billion of senior secured syndicated credit facilities maturing December 16, 2024, consisting of a $1.0 billion 5-year revolving credit facility and a fully drawn $400 million 5-year term loan A facility.  The revolving credit facility can be used for borrowings and letters of credit to fund HESM Opco’s operating activities, capital expenditures, distributions and for other general corporate purposes.  Borrowings under the 5-year term loan A facility will generally bear interest at LIBOR plus an applicable margin ranging from 1.55% to 2.50%, while the applicable margin for the 5-year syndicated revolving credit facility ranges from 1.275% to 2.000%.  Pricing levels for the facility fee and interest-rate margins are based on HESM Opco’s ratio of total debt to EBITDA (as defined in the credit facilities).  If HESM Opco obtains an investment grade credit rating, the pricing levels will be based on HESM Opco’s credit ratings in effect from time to time.  The credit facilities contain covenants that require HESM Opco to maintain a ratio of total debt to EBITDA (as defined in the credit facilities) for the prior four fiscal quarters of not

28

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)  

greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to HESM Opco obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter.  HESM Opco was in compliance with these financial covenants at June 30, 2020.  The credit facilities are secured by first-priority perfected liens on substantially all the presently owned and after-acquired assets of HESM Opco and its direct and indirect wholly owned material domestic subsidiaries, including equity interests directly owned by such entities, subject to certain customary exclusions.  At June 30, 2020, borrowings of $104 million were drawn under HESM Opco’s revolving credit facility, and borrowings of $400 million, excluding deferred issuance costs, were drawn under HESM Opco’s term loan A facility.  Borrowings under these credit facilities are non-recourse to Hess Corporation. 

Market Risk Disclosures

We are exposed in the normal course of business 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.  See Note 12, Financial Risk Management Activities, in the Notes to Consolidated Financial Statements.

We have outstanding foreign exchange contracts with notional amounts totaling $74 million at June 30, 2020 that are used to reduce our exposure to fluctuating foreign exchange rates for various currencies.  The change in fair value of foreign exchange contracts from a 10% strengthening in the U.S. Dollar exchange rate is estimated to be a loss of less than $5 million at June 30, 2020.

At June 30, 2020, our total long-term debt, which was substantially comprised of fixed-rate instruments, had a carrying value of $8,210 million and a fair value of $8,736 million.  A 15% increase or decrease in interest rates would decrease or increase the fair value of debt by approximately $460 million or $510 million, respectively.  Any changes in interest rates do not impact our cash outflows associated with fixed-rate interest payments or settlement of debt principal, unless a debt instrument is repurchased prior to maturity.

At June 30, 2020, we have outstanding WTI and Brent crude oil put option contracts.  As of June 30, 2020, an assumed 10% increase in the forward WTI and Brent crude oil prices used in determining the fair value of our put options would reduce the fair value of these derivative instruments by approximately $90 million, while an assumed 10% decrease in the same crude oil prices would increase the fair value of these derivative instruments by approximately $115 million.

29

PART I - FINANCIAL INFORMATION (CONT'D.)

Cautionary Note Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q, including information incorporated by reference herein, contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended.  Words such as “anticipate,” “estimate,” “expect,” “forecast,” “guidance,” “could,” “may,” “should,” “would,” “believe,” “intend,” “project,” “plan,” “predict,” “will,” “target” and similar expressions identify forward-looking statements, which are not historical in nature.  Our forward-looking statements may include, without limitation: our future financial and operational results; our business strategy; estimates of our crude oil and natural gas reserves and levels of production; benchmark prices of crude oil, natural gas liquids and natural gas and our associated realized price differentials; our projected budget and capital and exploratory expenditures; expected timing and completion of our development projects; and future economic and market conditions in the oil and gas industry.

Forward-looking statements are based on our current understanding, assessments, estimates and projections of relevant factors and reasonable assumptions about the future. Forward-looking statements are subject to certain known and unknown risks and uncertainties that could cause actual results to differ materially from our historical experience and our current projections or expectations of future results expressed or implied by these forward-looking statements.  The following important factors could cause actual results to differ materially from those in our forward-looking statements:

•fluctuations in market prices of crude oil, natural gas liquids and natural gas and competition in the oil and gas exploration and production industry, including as a result of the global COVID-19 pandemic;

•potential disruption or interruption of our operations due to catastrophic events, such as accidents, severe weather, geological events, shortages of skilled labor, cyber-attacks or health measures related to COVID-19;

•reduced demand for our products, including due to the global COVID-19 pandemic or the outbreak of any other public health threat, or due to the impact of competing or alternative energy products and political conditions and events, such as instability, changes in governments, armed conflict and economic sanctions;

•potential failures or delays in increasing oil and gas reserves, including as a result of unsuccessful exploration activity, drilling risks and unforeseen reservoir conditions;

•potential failures or delays in achieving expected production levels given inherent uncertainties in estimating quantities of proved reserves;

•changes in tax, property, contract and other laws, regulations and governmental actions applicable to our business, including legislative and regulatory initiatives regarding environmental concerns, such as measures to limit greenhouse gas emissions and well fracking bans;

•the ability of our contractual counterparties to satisfy their obligations to us, including the operation of joint ventures under which we may not control;

•unexpected changes in technical requirements for constructing, modifying or operating exploration and production facilities and/or the inability to timely obtain or maintain necessary permits;

•availability and costs of employees and other personnel, drilling rigs, equipment, supplies and other required services;

•any limitations on our access to capital or increase in our cost of capital as a result of weakness in the oil and gas industry or negative outcomes within commodity and financial markets;

•liability resulting from litigation, including heightened risks associated with being a general partner of Hess Midstream LP; and

•other factors described in the section entitled “Risk Factors” in this Quarterly Report on Form 10-Q and in Item 1A—Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019 as well as any additional risks described in our other filings with the SEC.

As and when made, we believe that our forward-looking statements are reasonable.  However, given these risks and uncertainties, caution should be taken not to place undue reliance on any such forward-looking statements since such statements speak only as of the date when made and there can be no assurance that such forward-looking statements will occur and actual results may differ materially from those contained in any forward-looking statement we make.  Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether because of new information, future events or otherwise.

30

PART I - FINANCIAL INFORMATION (CONT'D.)

Item 3.   Quantitative and Qualitative Disclosures about Market Risk.

The information required by this item is presented under Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk Disclosures.” 

Item 4.   Controls and Procedures.

Based upon their evaluation of the Corporation’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2020, John B. Hess, Chief Executive Officer, and John P. Rielly, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of June 30, 2020.

There was no change in internal control over financial reporting identified in connection with the evaluation required by paragraph (d) of Rules 13a-15 or 15d-15 in the quarter ended June 30, 2020 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

31

PART II – OTHER INFORMATION

Item 1.      Legal Proceedings.

Information regarding legal proceedings is contained in Note 10, Guarantees and Contingencies in the Notes to Consolidated Financial Statements and is incorporated herein by reference.

Item 1A.   Risk Factors.

Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019 and Part II, Item 1A. Risk Factors in our Form 10-Q for the fiscal quarter ended March 31, 2020 include certain risk factors that could materially affect our business, financial condition, or future results.  Those risk factors have not materially changed, except as set forth and as supplemented below:

Our business and operations have been and may continue to be adversely affected by the COVID-19 global pandemic or other similar public health developments and the recent reduced demand for oil and natural gas.

The COVID-19 global pandemic and related actions taken by governments and businesses, including voluntary and mandatory quarantines and travel and other restrictions, has resulted in a significant and swift reduction in economic activity.  Certain jurisdictions have begun re-opening only to return to restrictions in the face of increases in new COVID-19 cases. As a result of the COVID-19 global pandemic, our operations, and those of our business partners, service companies and suppliers, have experienced and may continue to experience further adverse effects, including disruptions, delays or temporary suspensions of operations and supply chains; temporary inaccessibility or closures of facilities; and workforce impacts from illness, school closures and other community response measures.  We have implemented a variety of health and safety measures including enhanced cleaning procedures and modified work practices such as travel restrictions, health screenings, reduced personnel at offshore platforms and onshore work sites wherever this can be done safely, and remote working arrangements for office workers.  There is no certainty that these or any other future measures will be sufficient to mitigate the risks posed by the disease, including the risk of infection of key employees, and our ability to perform certain functions could be impaired by these new business practices. For example, our reliance on technology has necessarily increased due to our encouragement of remote communications and other work-from-home practices, which could make us more vulnerable to cyber attacks. To the extent we or our business partners, service companies or suppliers continue to experience restrictions or other effects, our financial condition, results of operations and future expansion projects may be adversely affected.

In addition to the global health concerns of COVID-19, the pandemic has negatively affected the United States and global economy and severely adversely impacted demand for oil and natural gas.  The prolonged continuation or amplification of the outbreak of COVID-19 could result in further economic downturn that may affect our operating results in the long-term.  In addition, the effects of COVID-19 and concerns regarding its global spread have negatively impacted the domestic and international demand for crude oil and natural gas, which has contributed to price volatility and adversely affected the demand for and marketability of crude oil, natural gas and NGLs. Containment measures implemented to mitigate the spread of COVID-19 could continue to be widespread and lead to sustained adoption of certain behavioral changes, such as reduced travel and work-from-home policies, which could result in further reductions in demand for and consumption of energy commodities. The reduction in consumer demand for crude oil, natural gas and NGLs has created a supply imbalance, which could require further curtailments and shut-ins of production by the industry and further increase the costs of commercial storage and midstream contracts.

The timeline and potential magnitude of the COVID-19 pandemic remains unknown.  In the event one or more of our business partners is adversely affected by COVID-19 or the current market environment, that may impact our costs and ability to conduct business with them.  In addition, we may face an increased risk of changes in the regulation related to our business, such as the imposition of limitations on the production of oil and gas by states or other jurisdictions, that may result in additional limits on our products.  We also are subject to litigation risk and possible loss contingencies related to COVID-19, including with respect to commercial contracts, employee matters and insurance arrangements.  We may face additional asset impairments, decreases in proved reserves, along with other accounting charges as demand for crude oil, natural gas and NGLs decreases.  The current environment may make it more difficult to comply with covenants and other restrictions in agreements governing our debt, and a lack of confidence in our industry on the part of the financial markets may result in a lack of access to capital, any of which could lead to reduced liquidity.

As the impact from the COVID-19 pandemic remains difficult to predict, the extent to which it may negatively affect our operating results is uncertain.  Any impact will depend on future developments and new information that may emerge regarding the severity and duration of COVID-19 and the actions taken by authorities to contain it or treat its impact, all of which are beyond our control.  To the extent the COVID-19 pandemic adversely affects our business and financial results, it may also have the effect of heightening many of the other risks described in our annual report on Form 10-K for the year ended December 31, 2019.

32

PART II – OTHER INFORMATION (CONT'D)

Item 6.   Exhibits. 

Exhibits
3(1)	By-Laws of Hess Corporation (as amended effective May 6, 2020), incorporated by reference to Exhibit 3(1) of Form 10-Q of Registrant for the three months ended March 31, 2020.
10(1)	Amendment No. 1 dated as of June 9, 2020 to the Term Loan Agreement dated as of March 16, 2020, among Hess Corporation, the lenders party thereto, and JPMorgan Chase Bank, N.A., as administrative agent.
31(1)	Certification required by Rule 13a-14(a) (17 CFR 240.13a-14(a)) or Rule 15d-14(a) (17 CFR 240.15d-14(a)).
31(2)	Certification required by Rule 13a-14(a) (17 CFR 240.13a-14(a)) or Rule 15d-14(a) (17 CFR 240.15d-14(a)).
32(1)	Certification required by Rule 13a-14(b) (17 CFR 240.13a-14(b)) or Rule 15d-14(b) (17 CFR 240.15d-14(b)) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350).
32(2)	Certification required by Rule 13a-14(b) (17 CFR 240.13a-14(b)) or Rule 15d-14(b) (17 CFR 240.15d-14(b)) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350).
101(INS)	Inline XBRL Instance Document- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101(SCH)	Inline XBRL Taxonomy Extension Schema Document.
101(CAL)	Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101(LAB)	Inline XBRL Taxonomy Extension Label Linkbase Document.
101(PRE)	Inline XBRL Taxonomy Extension Presentation Linkbase Document.
101(DEF)	Inline XBRL Taxonomy Extension Definition Linkbase Document.
104	The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2020, has been formatted in Inline XBRL.

33

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

HESS CORPORATION
(REGISTRANT)
By	/s/ John B. Hess
	JOHN B. HESS
	CHIEF EXECUTIVE OFFICER
By	/s/ John P. Rielly
	JOHN P. RIELLY
	EXECUTIVE VICE PRESIDENT AND
	CHIEF FINANCIAL OFFICER

Date: August 6, 2020

34

EX-10.1

Exhibit 10(1)

AMENDMENT NO. 1 dated as of June 9, 2020 (this “Amendment”), to the Term Loan Agreement dated as of March 16, 2020 (the “Existing Credit Agreement”), among HESS CORPORATION, a Delaware corporation; the LENDERS from time to time party thereto; and JPMORGAN CHASE BANK, N.A., as administrative agent.

WHEREAS, the Borrower has requested that the Existing Credit Agreement be amended as set forth herein;

WHEREAS, in connection with the syndication of the Facility and in addition to JPMorgan Chase Bank, N.A. as a joint lead arranger and joint bookrunner, the Borrower intends to appoint each of Goldman Sachs Bank USA, Sumitomo Mitsui Banking Corporation and Citibank, N.A. as a joint lead arranger and joint bookrunner, and DNB Markets, Inc. as a senior managing agent, for the Facility, effective upon such Person (or an Affiliate thereof) becoming a Lender under the Facility; and

WHEREAS, each of the Lenders party hereto, collectively constituting all of the Lenders under the Existing Credit Agreement, is willing to agree to amend the Existing Credit Agreement on the terms and subject to the conditions set forth herein (the Existing Credit Agreement, as so amended, being referred to herein as the “Amended Credit Agreement”).

NOW THEREFORE, in consideration of the mutual agreements herein contained and other good and valuable consideration, the sufficiency and receipt of which are hereby acknowledged, the parties hereto agree as follows:

SECTION 1. Defined Terms. Each capitalized term used and not otherwise defined herein shall have the meaning assigned to such term in the Amended Credit Agreement.

SECTION 2. Amendments to Existing Credit Agreement. (a) The cover of the Existing Credit Agreement is hereby amended to be in the form of Exhibit A hereto.

(b) The ninth paragraph of Article VIII of the Existing Credit Agreement is hereby amended and restated as follows:

“None of the Arranger or any other Person appointed as a joint lead arranger or joint bookrunner, senior managing agent or other similar title in connection with the Facility shall have any duties or obligations under this Agreement or any other Loan Document (except in its capacity, as applicable, as the Administrative Agent or as a Lender), but each of the Arranger and such other Persons shall have the benefit of the indemnities provided for hereunder.”

(c) Each other reference in Articles VIII and IX of the Existing Credit Agreement to the Arranger is hereby deemed to include a reference to any other Person appointed as a joint lead arranger or joint bookrunner in connection with the Facility.

SECTION 3. Effectiveness. This Amendment and the amendment of the Existing Credit Agreement as set forth in Section 2 hereof shall become effective as of the first date (the “Amendment No. 1 Effective Date”) on which each of the following conditions precedent shall have been satisfied or waived:

(a) The Administrative Agent shall have received from the Borrower and each of the Lenders under the Existing Credit Agreement as in effect immediately prior to the Amendment No. 1 Effective Date either (i) a counterpart of this Amendment signed on behalf of such party or (ii) evidence satisfactory to the Administrative Agent (which may include a facsimile or electronic transmission) that such party has signed a counterpart of this Amendment.

(b)The Administrative Agent shall have received, to the extent invoiced, reimbursement or payment of all out of pocket expenses (including fees, charges and disbursements of counsel) required to be reimbursed or paid by the Borrower in connection with this Amendment.

The Administrative Agent shall promptly notify, in writing, the Borrower and the Lenders of the Amendment No. 1 Effective Date, and such notice shall be conclusive and binding.

SECTION 4. Appointment of Additional Titles. In addition to JPMorgan Chase Bank, N.A. as a joint lead arranger and joint bookrunner, the Borrower hereby appoints each of Goldman Sachs Bank USA, Sumitomo Mitsui Banking Corporation and Citibank, N.A. as a joint lead arranger and joint bookrunner, and DNB Markets, Inc. as a senior managing agent, in connection with the Facility, in each case effective upon such Person (or an Affiliate thereof) becoming a Lender under the Facility.

SECTION 5. Effect of Amendment.

(a)Except as expressly set forth herein, this Amendment shall not by implication or otherwise limit, impair, constitute a waiver of, or otherwise affect the rights and remedies of the Lenders or the Administrative Agent under the Existing Credit Agreement or any other Loan Document, and shall not alter, modify, amend or in any way affect any of the terms, conditions, obligations, covenants or agreements contained in the Existing Credit Agreement or any other Loan Document, all of which are ratified and affirmed in all respects and shall continue in full force and effect. Nothing herein shall be deemed to entitle the Borrower to a consent to, or a waiver, amendment, modification or other change of, any of the terms, conditions, obligations, covenants or agreements contained in the Amended Credit Agreement or any other Loan Document in similar or different circumstances. This Amendment shall constitute a “Loan Document” for all purposes of the Amended Credit Agreement and the other Loan Documents.

(b)On and after the Amendment No. 1 Effective Date, each reference in the Existing Credit Agreement to “this Agreement”, “hereunder”, “hereof”, “herein” or words of like import, as used in the Existing Credit Agreement, shall refer to the Existing Credit Agreement as amended hereby.

SECTION 6. Counterparts. This Amendment may be executed in counterparts (and by different parties hereto on different counterparts), each of which shall constitute an original, but all of which when taken together shall constitute a single contract. Delivery of an

2

executed counterpart of a signature page of this Amendment by facsimile, e-mailed .pdf or any other electronic image shall be effective as delivery of a manually executed counterpart of this Amendment.

SECTION 7. Governing Law. This Amendment shall be construed in accordance with and governed by the law of the State of New York.

SECTION 8. Headings. Section headings used herein are for convenience of reference only, are not part of this Amendment and shall not affect the construction of, or be taken into consideration in interpreting, this Amendment.

SECTION 9. Incorporation by Reference. Sections 10.07(b), 10.08, 10.10(b), 10.10(c), 10.10(d), 10.11 and 10.13 of the Existing Credit Agreement are hereby incorporated by reference herein, mutatismutandis.

[THE REMAINDER OF THIS PAGE IS INTENTIONALLY LEFT BLANK]

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IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be duly executed by their respective authorized officers as of the day and year first above written.

HESS CORPORATION

by

/s/ John P. Rielly

Name: John P. Rielly

Title: Executive Vice President and

Chief Financial Officer

[Signature Page to Amendment No. 1 to the Term Loan Agreement]

JPMORGAN CHASE BANK, N.A.,

as Administrative Agent and a Lender

by

/s/ Arina Mavilian

Name: Arina Mavilian

Title: Authorized Signatory

Exhibit A

[See Attached]

TERM LOAN AGREEMENT

dated as of March 16, 2020,

among

HESS CORPORATION,

THE LENDERS PARTY HERETO,

and

JPMORGAN CHASE BANK, N.A.,

as Administrative Agent

_________________________

JPMORGAN CHASE BANK, N.A.,

GOLDMAN SACHS BANK USA,

SUMITOMO MITSUI BANKING CORPORATION

and

CITIBANK, N.A.,

as Joint Lead Arrangers and Joint Bookrunners

DNB MARKETS, INC.,

as Senior Managing Agent

_________________________

[CS&M Ref No. 6701-425]

EX-31.1

Exhibit 31(1)

CERTIFICATIONS

I, John B. Hess, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Hess Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

By	/s/ John B. Hess
	JOHN B. HESS
	CHIEF EXECUTIVE OFFICER

Date:  August 6, 2020

EX-31.2

Exhibit 31(2)

I, John P. Rielly, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Hess Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

By	/s/ John P. Rielly
	JOHN P. RIELLY
	EXECUTIVE VICE PRESIDENT AND
	CHIEF FINANCIAL OFFICER

Date:  August 6, 2020

EX-32.1

Exhibit 32(1)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Hess Corporation (the "Corporation") on Form 10-Q for the period ending June 30, 2020 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, John B. Hess, Chief Executive Officer of the Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

By	/s/ John B. Hess
	JOHN B. HESS
	CHIEF EXECUTIVE OFFICER
	Date: August 6, 2020

A signed original of this written statement required by Section 906 has been provided to Hess Corporation and will be retained by Hess Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32(2)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Hess Corporation (the "Corporation") on Form 10-Q for the period ending June 30, 2020 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, John P. Rielly, Senior Vice President and Chief Financial Officer of the Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

By	/s/ John P. Rielly
	JOHN P. RIELLY
	EXECUTIVE VICE PRESIDENT AND
	CHIEF FINANCIAL OFFICER
	Date: August 6, 2020

A signed original of this written statement required by Section 906 has been provided to Hess Corporation and will be retained by Hess Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Cover Page	6 Months Ended
	Jun. 30, 2020 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	1-1204
Entity Registrant Name	HESS CORPORATION
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
Title of 12(b) Security	Common Stock
Trading Symbol	HES
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	307,144,424
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Central Index Key	0000004447
Current Fiscal Year End Date	--12-31

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CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current Assets:
Cash and cash equivalents	$ 1,646	$ 1,545
Accounts receivable:
From contracts with customers	428	940
Joint venture and other	168	230
Crude oil derivative contracts	450	125
Inventories	360	261
Other current assets	63	55
Total current assets	3,115	3,156
Property, plant and equipment:
Total — at cost	32,209	35,820
Less: Reserves for depreciation, depletion, amortization and lease impairment	17,384	19,006
Property, plant and equipment — net	14,825	16,814
Operating lease right-of-use assets — net	344	447
Finance lease right-of-use assets — net	182	299
Goodwill	360	360
Deferred income taxes	78	80
Other assets	642	626
Total Assets	19,546	21,782
Current Liabilities:
Accounts payable	307	411
Accrued liabilities	1,110	1,803
Taxes payable	34	97
Current maturities of long-term debt	5	0
Current portion of operating and finance lease obligations	108	199
Total current liabilities	1,564	2,510
Long-term debt	8,205	7,142
Long-term operating lease obligations	349	353
Long-term finance lease obligations	229	238
Deferred income taxes	319	415
Asset retirement obligations	944	897
Other liabilities and deferred credits	570	521
Total Liabilities	12,180	12,076
Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized - 600,000,000 shares, Issued - 307,144,424 shares (2019: 304,955,472)	307	305
Capital in excess of par value	5,650	5,591
Retained earnings	625	3,535
Accumulated other comprehensive income (loss)	(187)	(699)
Total Hess Corporation stockholders’ equity	6,395	8,732
Noncontrolling interests	971	974
Total Equity	7,366	9,706
Total Liabilities and Equity	$ 19,546	$ 21,782

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CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 1.00	$ 1.00
Common stock, shares authorized (in shares)	600,000,000	600,000,000
Common stock, shares issued (in shares)	307,144,424	304,955,472

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STATEMENT OF CONSOLIDATED INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Revenues and Non-Operating Income
Sales and other operating revenues	$ 833	$ 1,660	$ 2,187	$ 3,232
(Gains) losses on asset sales, net	8	22	8	22
Other, net	1	15	16	42
Total revenues and non-operating income	842	1,697	2,211	3,296
Costs and Expenses
Marketing, including purchased oil and gas	56	477	434	885
Operating costs and expenses	294	285	597	551
Production and severance taxes	16	46	58	85
Exploration expenses, including dry holes and lease impairment	31	43	220	77
General and administrative expenses	89	89	191	176
Interest expense	119	97	232	195
Depreciation, depletion and amortization	509	494	1,070	992
Impairment	0	0	2,126	0
Total costs and expenses	1,114	1,531	4,928	2,961
Income (Loss) Before Income Taxes	(272)	166	(2,717)	335
Provision (benefit) for income taxes	(9)	132	(88)	226
Net Income (Loss)	(263)	34	(2,629)	109
Less: Net income (loss) attributable to noncontrolling interests	57	40	124	83
Net Income (Loss) Attributable to Hess Corporation	(320)	(6)	(2,753)	26
Less: Preferred stock dividends	0	0	0	4
Net income (loss) attributable to Hess Corporation Common Stockholders	$ (320)	$ (6)	$ (2,753)	$ 22
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic (in dollars per share)	$ (1.05)	$ (0.02)	$ (9.04)	$ 0.07
Diluted (in dollars per share)	$ (1.05)	$ (0.02)	$ (9.04)	$ 0.07
Weighted Average Number of Common Shares Outstanding:
Basic (in shares)	305.0	302.2	304.5	299.8
Diluted (in shares)	305.0	302.2	304.5	302.1
Common Stock Dividends Per Share (in dollars per share)	$ 0.25	$ 0.25	$ 0.50	$ 0.50

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STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ (263)	$ 34	$ (2,629)	$ 109
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	(228)	14	(292)	(1)
Income taxes on effect of hedge (gains) losses reclassified to income	0	0	0	0
Net effect of hedge (gains) losses reclassified to income	(228)	14	(292)	(1)
Change in fair value of cash flow hedges	(214)	0	776	(346)
Income taxes on change in fair value of cash flow hedges	0	0	0	0
Net change in fair value of cash flow hedges	(214)	0	776	(346)
Change in derivatives designated as cash flow hedges, after taxes	(442)	14	484	(347)
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	4	(24)	4	(18)
Income taxes on actuarial changes in plan liabilities	0	0	0	0
(Increase) reduction in unrecognized actuarial losses, net	4	(24)	4	(18)
Amortization of net actuarial losses	12	12	24	23
Income taxes on amortization of net actuarial losses	0	0	0	0
Net effect of amortization of net actuarial losses	12	12	24	23
Change in pension and other postretirement plans, after taxes	16	(12)	28	5
Other Comprehensive Income (Loss)	(426)	2	512	(342)
Comprehensive Income (Loss)	(689)	36	(2,117)	(233)
Less: Comprehensive income (loss) attributable to noncontrolling interests	57	40	124	83
Comprehensive Income (Loss) Attributable to Hess Corporation	$ (746)	$ (4)	$ (2,241)	$ (316)

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STATEMENT OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash Flows From Operating Activities
Net income (loss)	$ (2,629)	$ 109
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Gains) losses on asset sales, net	(8)	(22)
Depreciation, depletion and amortization	1,070	992
Impairment	2,126	0
Exploratory dry hole costs	135	0
Exploration lease and other impairment	38	11
Stock compensation expense	47	48
Noncash (gains) losses on commodity derivatives, net	119	58
Provision (benefit) for deferred income taxes and other tax accruals	(95)	(1)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	628	(70)
(Increase) decrease in inventories	(99)	(33)
Increase (decrease) in accounts payable and accrued liabilities	(520)	(130)
Increase (decrease) in taxes payable	(63)	14
Changes in other operating assets and liabilities	(38)	(63)
Net cash provided by (used in) operating activities	711	913
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(1,250)	(1,085)
Additions to property, plant and equipment - Midstream	(147)	(210)
Payments for Midstream equity investments	0	(23)
Proceeds from asset sales, net of cash sold	11	22
Other, net	(2)	(1)
Net cash provided by (used in) investing activities	(1,388)	(1,297)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	72	160
Debt with maturities of greater than 90 days – Borrowings	1,000	0
Debt with maturities of greater than 90 days - Repayments	0	(5)
Payments on finance lease obligations	(3)	(45)
Common stock acquired and retired	0	(25)
Cash dividends paid	(157)	(164)
Noncontrolling interests, net	(128)	(27)
Other, net	(6)	4
Net cash provided by (used in) financing activities	778	(102)
Net Increase (Decrease) in Cash and Cash Equivalents	101	(486)
Cash and Cash Equivalents at Beginning of Year	1,545	2,694
Cash and Cash Equivalents at End of Period	$ 1,646	$ 2,208

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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, 2018	$ 10,888	$ 1	$ 291	$ 5,386	$ 4,257	$ (306)	$ 9,629	$ 1,259
Net income (loss)	109				26		26	83
Other comprehensive income (loss)	(342)					(342)	(342)
Preferred stock conversion	0	(1)	(12)	(11)			0
Share-based compensation	61		1	60			61
Dividends on preferred stock	(4)				(4)		(4)
Dividends on common stock	(154)				(154)		(154)
Sale of water business to Hess Infrastructure Partners	0			78			78	(78)
Noncontrolling interests, net	(27)							(27)
Balance at Jun. 30, 2019	10,531	0	304	5,513	4,125	(648)	9,294	1,237
Balance at Mar. 31, 2019	10,553	0	304	5,481	4,207	(650)	9,342	1,211
Net income (loss)	34				(6)		(6)	40
Other comprehensive income (loss)	2					2	2
Share-based compensation	32			32			32
Dividends on common stock	(76)				(76)		(76)
Noncontrolling interests, net	(14)							(14)
Balance at Jun. 30, 2019	10,531	0	304	5,513	4,125	(648)	9,294	1,237
Balance at Dec. 31, 2019	9,706	0	305	5,591	3,535	(699)	8,732	974
Net income (loss)	(2,629)				(2,753)		(2,753)	124
Other comprehensive income (loss)	512					512	512
Share-based compensation	56		2	59	(5)		56
Dividends on common stock	(152)				(152)		(152)
Noncontrolling interests, net	(127)							(127)
Balance at Jun. 30, 2020	7,366	0	307	5,650	625	(187)	6,395	971
Balance at Mar. 31, 2020	8,178	0	307	5,633	1,021	239	7,200	978
Net income (loss)	(263)				(320)		(320)	57
Other comprehensive income (loss)	(426)					(426)	(426)
Share-based compensation	17		0	17	0		17
Dividends on common stock	(76)				(76)		(76)
Noncontrolling interests, net	(64)							(64)
Balance at Jun. 30, 2020	$ 7,366	$ 0	$ 307	$ 5,650	$ 625	$ (187)	$ 6,395	$ 971

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Basis of Presentation

6 Months Ended

Jun. 30, 2020

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 June 30, 2020 and December 31, 2019, the consolidated results of operations for the three and six months ended June 30, 2020 and 2019, and consolidated cash flows for the six months ended June 30, 2020 and 2019.  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, 2019.

In the first quarter of 2020, we adopted 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 prior "incurred loss" model.  We calculate expected credit losses for our receivables using the probability of default and the expected loss given default.  Historical data, current market conditions, and forecasts of future economic conditions are used to determine the probability of default and the expected loss given default.  The adoption of this ASU did not have a material impact to our financial statements.

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Inventories

6 Months Ended

Jun. 30, 2020

Inventory Disclosure [Abstract]

Inventories

2.  Inventories

Inventories consisted of the following:

	June 30, 2020		December 31, 2019
	(In millions)
Crude oil and natural gas liquids	$	204	$	92
Materials and supplies	156		169
Total Inventories	$	360	$	261

We have chartered three very large crude carriers (VLCCs) to load a total of approximately 6 million barrels of oil during May through August to sell in Asian markets later this year. During the second quarter, the Corporation loaded 3.7 million barrels of Bakken crude oil on VLCCs and included costs of the produced volumes totaling $113 million in crude oil inventories with a corresponding reduction to Marketing, including purchased oil and gas. In the first quarter of 2020, we recognized charges of $53 million ($52 million after income taxes) recorded in Marketing, including purchased oil and gas to reflect crude oil inventories at net realizable value.

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Property Plant and Equipment

6 Months Ended

Jun. 30, 2020

Property, Plant and Equipment [Abstract]

Property Plant and Equipment

3.  Property Plant and Equipment

Capitalized Exploratory Well Costs:  

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the six months ended June 30, 2020 (in millions):

Balance at January 1, 2020	$	584
Additions to capitalized exploratory well costs pending the determination of proved reserves	70
Capitalized exploratory well costs charged to expense	(125)
Balance at June 30, 2020	$	529

The table above does not include well costs incurred and expensed during the first six months of 2020 of $10 million associated with the Oldfield-1 well in the Gulf of Mexico. In the first quarter of 2020, the Corporation expensed previously capitalized well costs of $125 million, primarily related to the northern portion of the Shenzi Field (Hess 28%) in the Gulf of Mexico due to reprioritization of the Corporation’s forward capital program in response to the significant decline in crude oil prices.  Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $360 million at June 30, 2020 and primarily related to:  

Guyana: Approximately 80% of the capitalized well costs in excess of one year relate to 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.

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 ongoing commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block.

Malaysia:  Approximately 10% of the capitalized well costs in excess of one year relate to the North Malay Basin (Hess 50%), offshore Peninsular Malaysia, where hydrocarbons were encountered in five successful exploration wells.  Subsurface evaluation and pre-development studies for future phases of development are ongoing.

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Hess Midstream LP

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Hess Midstream LP

4.  Hess Midstream LP

At June 30, 2020 Hess Midstream LP (Hess Midstream), a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling $1,972 million (December 31, 2019: $1,941 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream assets available to settle the obligations of Hess Midstream include cash and cash equivalents totaling $3 million (December 31, 2019: $3 million) and property, plant and equipment with a carrying value of $3,069 million (December 31, 2019: $3,010 million).

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Debt

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Debt

5.  Debt

In the first quarter of 2020, we entered into a $1.0 billion three year term loan agreement with a maturity date of March 16, 2023.  In the second quarter of 2020, we successfully syndicated the loan. Borrowings under the term loan generally bear interest at LIBOR plus an applicable margin of 2.25%. The applicable margin varies based on the credit rating of the Corporation’s senior, unsecured, non-credit enhanced long-term debt, and will increase by 0.25% on each anniversary of the term loan. The term loan agreement contains customary representations, warranties and covenants, including the same financial covenant as our revolving credit facility which limits the ratio of Total Consolidated Debt to Total Capitalization (as such terms are defined in the revolving credit facility and term loan agreements) of the Corporation and its consolidated subsidiaries to 65%, and customary events of default.  At June 30, 2020, Hess Corporation had borrowings of $1.0 billion under this term loan agreement and was in compliance with this financial covenant.

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Revenue

6 Months Ended

Jun. 30, 2020

Revenue from Contract with Customer [Abstract]

Revenue

6.  Revenue

Revenue from contracts with customers on a disaggregated basis was as follows:

	Exploration and Production												Midstream		Eliminations		Total
	United States		Guyana		Malaysia & JDA		Denmark		Libya		E&P Total
	(In millions)
Three Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	254	$	31	$	1	$	14	$	—	$	300	$	—	$	—	$	300
Natural gas liquids revenue	43		—		—		—		—		43		—		—		43
Natural gas revenue	32		—		89		2		—		123		—		—		123
Sales of purchased oil and gas	143		—		—		—		—		143		—		—		143
Intercompany revenue	—		—		—		—		—		—		270		(270)		—
Total revenues from contracts with customers	472		31		90		16		—		609		270		(270)		609
Other operating revenues (a)	188		27		—		9		—		224		—		—		224
Total sales and other operating revenues	$	660	$	58	$	90	$	25	$	—	$	833	$	270	$	(270)	$	833
Three Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	762	$	—	$	24	$	51	$	130	$	967	$	—	$	—	$	967
Natural gas liquids revenue	48		—		—		—		—		48		—		—		48
Natural gas revenue	33		—		154		2		6		195		—		—		195
Sales of purchased oil and gas	439		—		—		—		22		461		—		—		461
Intercompany revenue	—		—		—		—		—		—		190		(190)		—
Total revenues from contracts with customers	1,282		—		178		53		158		1,671		190		(190)		1,671
Other operating revenues (a)	(11)		—		—		—		—		(11)		—		—		(11)
Total sales and other operating revenues	$	1,271	$	—	$	178	$	53	$	158	$	1,660	$	190	$	(190)	$	1,660
Six Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	919	$	69	$	3	$	50	$	—	$	1,041	$	—	$	—	$	1,041
Natural gas liquids revenue	91		—		—		—		—		91		—		—		91
Natural gas revenue	70		—		228		4		2		304		—		—		304
Sales of purchased oil and gas	459		1		—		—		—		460		—		—		460
Intercompany revenue	—		—		—		—		—		—		561		(561)		—
Total revenues from contracts with customers	1,539		70		231		54		2		1,896		561		(561)		1,896
Other operating revenues (a)	243		33		1		14		—		291		—		—		291
Total sales and other operating revenues	$	1,782	$	103	$	232	$	68	$	2	$	2,187	$	561	$	(561)	$	2,187
Six Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	1,444	$	—	$	45	$	67	$	221	$	1,777	$	—	$	—	$	1,777
Natural gas liquids revenue	116		—		—		—		—		116		—		—		116
Natural gas revenue	75		—		334		5		12		426		—		—		426
Sales of purchased oil and gas	865		—		—		—		44		909		—		—		909
Intercompany revenue	—		—		—		—		—		—		380		(380)		—
Total revenues from contracts with customers	2,500		—		379		72		277		3,228		380		(380)		3,228
Other operating revenues (a)	4		—		—		—		—		4		—		—		4
Total sales and other operating revenues	$	2,504	$	—	$	379	$	72	$	277	$	3,232	$	380	$	(380)	$	3,232

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

There have been no significant changes to contracts with customers or composition thereof during the six months ended June 30, 2020.  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.

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Impairment

6 Months Ended

Jun. 30, 2020

Asset Impairment Charges [Abstract]

Impairment

7.  Impairment

Oil and Gas Properties:

As a result of the significant decline in crude oil prices due to the global economic slowdown from the coronavirus (COVID-19) pandemic, we reviewed our oil and gas properties within the Exploration and Production operating segment for impairment in the first quarter of 2020.  We recognized pre-tax impairment charges in the first quarter of 2020 to reduce the carrying value of our oil and gas properties and certain related right-of-use assets at the North Malay Basin in Malaysia by $755 million ($755 million after income taxes), the South Arne Field in Denmark by $670 million ($594 million after income taxes), and in the Gulf of Mexico, the Stampede Field by $410 million ($410 million after income taxes) and the Tubular Bells Field by $270 million ($270 million after income taxes) primarily as a result of a lower long-term crude oil price outlook.  The impairment charges were based on estimates of fair value at March 31, 2020 determined by discounting internally developed future net cash flows, a Level 3 fair value measurement.  The total of the fair value estimates was approximately $1.05 billion.  Significant inputs used in determining the discounted future net cash flows include future prices, projected production volumes using risk adjusted oil and gas reserves, and discount rates.  The future pricing assumptions used were based on forward strip crude oil prices as of March 31, 2020 for the remainder of 2020 through 2022, and $50 per barrel for WTI ($55 per barrel for Brent) in 2023 and thereafter to the end of field life.  The weighted average crude oil benchmark price based on total projected crude oil volumes for the impaired assets was $48.82 per barrel.  A discount rate of 10% was used in each of the fair value measurements which represents the estimated discount rate a market participant would use.  We determined the discount rate by considering the weighted average cost of capital for a group of peer companies.

Other Assets:

In the first quarter of 2020, we recognized impairment charges totaling $21 million pre-tax ($20 million after income taxes) related to drilling rig right-of-use assets in the Bakken and surplus materials and supplies.

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Retirement Plans

6 Months Ended

Jun. 30, 2020

Retirement Benefits [Abstract]

Retirement Plans

8. Retirement Plans

Components of net periodic pension cost consisted of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Service cost	$	14	$	11	$	28	$	21
Interest cost (a)	19		24		37		48
Expected return on plan assets (a)	(45)		(45)		(90)		(90)
Amortization of unrecognized net actuarial losses (a)	12		12		24		23
Pension (income) expense (a)	$	—	$	2	$	(1)	$	2

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three and six months ended June 30, 2020 was income of $14 million and $29 million, respectively, compared with income of $9 million and $19 million for the three and six months ended June 30, 2019, respectively.

To preserve cash in 2020, we are minimizing non-required cash contributions to funded pension plans.  In 2020, we expect to contribute approximately $2 million to our funded pension plans.

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Weighted Average Common Shares

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Weighted Average Common Shares

9.  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 June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net income (loss)	$	(263)	$	34	$	(2,629)	$	109
Less: Net income (loss) attributable to noncontrolling interests	57		40		124		83
Less: Preferred stock dividends	—		—		—		4
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(320)	$	(6)	$	(2,753)	$	22
Weighted average number of common shares outstanding:
Basic	305.0		302.2		304.5		299.8
Effect of dilutive securities
Restricted common stock	—		—		—		0.9
Stock options	—		—		—		0.2
Performance share units	—		—		—		1.2
Diluted	305.0		302.2		304.5		302.1

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
Restricted common stock	2,173,061	2,156,525	2,094,360	28,970
Stock options	4,429,642	4,894,731	4,239,533	2,920,944
Performance share units	992,166	1,858,050	1,144,261	32,831
Common shares from conversion of preferred stock	—	—	—	1,954,473

During the six months ended June 30, 2020, we granted 1,120,356 shares of restricted stock (2019: 945,009), 307,999 performance share units (2019: 234,866) and 686,639 stock options (2019: 526,968).

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Guarantees and Contingencies

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Guarantees and Contingencies

10.  Guarantees and Contingencies

We are subject to loss contingencies with respect to various claims, lawsuits and other proceedings.  A liability is recognized in our consolidated financial statements when it is probable that a loss has been incurred and the amount can be reasonably estimated.  If the risk of loss is probable, but the amount cannot be reasonably estimated or the risk of loss is only reasonably possible, a liability is not accrued; however, we disclose the nature of those contingencies.  We cannot predict with certainty if, how or when existing claims, lawsuits and proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages.

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

groundwater in Maryland by introducing thereto gasoline with MTBE.  The suit filed in Maryland state court, was served on us in January 2018 and has been removed to Federal court by the defendants.

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

In March 2014, we received an Administrative Order from the EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York.  Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected shipbuilding and repair facility adjacent to the Canal.  The remedy selected by the EPA includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap.  The EPA’s original estimate was that this remedy would cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain.  We have complied with the EPA’s March 2014 Administrative Order and contributed funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert.  In January 2020, we received an additional Administrative Order from the EPA requiring us and several other parties to begin Remedial Action along the uppermost portion of the Canal.  We intend to comply with this Administrative Order.  The remediation work is anticipated to begin in the fourth quarter of 2020.  The costs will continue to be allocated amongst the parties, as they were for the Remedial Design.  

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

From time to time, we are involved in other judicial and administrative proceedings, including proceedings relating to other environmental matters.  We cannot predict with certainty if, how or when such proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages.  Numerous issues may need to be resolved, including through potentially lengthy discovery and determination of important factual matters before a loss or range of loss can be reasonably estimated for any proceeding.

Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of lawsuits, claims and proceedings, including the matters disclosed above, is not expected to have a material adverse effect on our financial condition, results of operations or cash flows.  However, we could incur judgments, enter into settlements, or revise our opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations in the period in which the amounts are accrued and our cash flows in the period in which the amounts are paid.

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Segment Information

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Segment Information

11.  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 June 30, 2020
Sales and Other Operating Revenues - Third parties	$	833	$	—	$	—	$	—	$	833
Intersegment Revenues	—		270		—		(270)		—
Sales and Other Operating Revenues	$	833	$	270	$	—	$	(270)	$	833
Net Income (Loss) attributable to Hess Corporation	$	(249)	$	51	$	(122)	$	—	$	(320)
Depreciation, Depletion and Amortization	470		39		—		—		509
Provision (Benefit) for Income Taxes	(11)		2		—		—		(9)
Capital Expenditures	428		79		—		—		507
For the Three Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	1,660	$	—	$	—	$	—	$	1,660
Intersegment Revenues	—		190		—		(190)		—
Sales and Other Operating Revenues	$	1,660	$	190	$	—	$	(190)	$	1,660
Net Income (Loss) attributable to Hess Corporation	$	68	$	35	$	(109)	$	—	$	(6)
Depreciation, Depletion and Amortization	459		35		—		—		494
Provision (Benefit) for Income Taxes	131		—		1		—		132
Capital Expenditures	625		69		—		—		694
For the Six Months Ended June 30, 2020
Sales and Other Operating Revenues - Third parties	$	2,187	$	—	$	—	$	—	$	2,187
Intersegment Revenues	—		561		—		(561)		—
Sales and Other Operating Revenues	$	2,187	$	561	$	—	$	(561)	$	2,187
Net Income (Loss) attributable to Hess Corporation	$	(2,620)	$	112	$	(245)	$	—	$	(2,753)
Depreciation, Depletion and Amortization	991		77		2		—		1,070
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(88)		4		(4)		—		(88)
Capital Expenditures	1,037		136		—		—		1,173
For the Six Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	3,232	$	—	$	—	$	—	$	3,232
Intersegment Revenues	—		380		—		(380)		—
Sales and Other Operating Revenues	$	3,232	$	380	$	—	$	(380)	$	3,232
Net Income (Loss) attributable to Hess Corporation	$	177	$	72	$	(223)	$	—	$	26
Depreciation, Depletion and Amortization	923		69		—		—		992
Provision (Benefit) for Income Taxes	226		—		—		—		226
Capital Expenditures	1,140		196		—		—		1,336

Identifiable assets by operating segment were as follows:

	June 30, 2020		December 31, 2019
	(In millions)
Exploration and Production	$	14,267	$	16,790
Midstream	3,550		3,499
Corporate, Interest and Other	1,729		1,493
Total	$	19,546	$	21,782

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Financial Risk Management Activities

6 Months Ended

Jun. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Financial Risk Management Activities

12.  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 June 30, 2020, these forward contracts relate to the British Pound and the Danish Krone.  Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.

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

	June 30, 2020		December 31, 2019
	(In millions)
Commodity - crude oil put options (millions of barrels)	27.6		54.9
Foreign exchange forwards	$	74	$	90
Interest rate swaps	$	100	$	100

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

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

	Assets		Liabilities
	(In millions)
June 30, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	450	$	—
Interest rate swaps - Other assets (noncurrent)	6		—
Total derivative contracts designated as hedging instruments	456		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts receivable - Joint venture and other	2		—
Total derivative contracts not designated as hedging instruments	2		—
Gross fair value of derivative contracts	458		—
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	458	$	—
December 31, 2019
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	125	$	—
Interest rate swaps - Other assets (noncurrent)	1		—
Total derivative contracts designated as hedging instruments	126		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts payable	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	126		(1)
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	126	$	(1)

All fair values in the table above are based on Level 2 inputs.

Derivative contracts designated as hedging instruments:

Crude oil derivatives:  Crude oil hedging contracts increased Sales and other operating revenues by $228 million and $292 million in the three and six months ended June 30, 2020, respectively. In the three and six months ended June 30, 2019, the impact from crude oil hedging contracts on Sales and other operating revenues was a decrease of $14 million and an increase of $1 million, respectively. At June 30, 2020, pre-tax deferred gains in Accumulated other comprehensive income (loss) related to outstanding crude

oil price hedging contracts were $386 million which will be reclassified into earnings during the remainder of 2020 as the originally hedged crude oil sales are recognized in earnings.  

Interest rate swaps designated as fair value hedges:  At June 30, 2020 and December 31, 2019, we had interest rate swaps with gross notional amounts totaling $100 million, which were designated as fair value hedges and relate to debt where we have converted interest payments from fixed to floating rates.  Changes in the fair value of interest rate swaps and the hedged fixed-rate debt are recorded in Interest expense in the Statement of Consolidated Income.  In the three and six months ended June 30, 2020, the change in fair value of interest rate swaps was an increase in the asset of $1 million and $6 million, respectively, compared with a decrease in the liability of $2 million and $3 million in the three and six months ended June 30, 2019, 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 Revenues and non-operating income in the Statement of Consolidated Income were losses of $2 million and $3 million in the three and six months ended June 30, 2020, respectively, compared with losses of $2 million and gains of $3 million in the three and six months ended June 30, 2019, respectively.  A component of foreign exchange gains and losses is the result of foreign exchange derivative contracts that are not designated as hedges which amounted to net gains of $1 million and $3 million in the three and six months ended June 30, 2020, respectively, compared with net gains of $1 million and $1 million in the three and six months ended June 30, 2019, 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 June 30, 2020.  At June 30, 2020, total long-term debt, which was primarily comprised of fixed-rate debt instruments, had a carrying value of $8,210 million and a fair value of $8,736 million based on Level 2 inputs.

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Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New Accounting Pronouncements	In the first quarter of 2020, we adopted 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 prior "incurred loss" model.  We calculate expected credit losses for our receivables using the probability of default and the expected loss given default.  Historical data, current market conditions, and forecasts of future economic conditions are used to determine the probability of default and the expected loss given default.  The adoption of this ASU did not have a material impact to our financial statements.

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Inventories (Tables)

6 Months Ended

Jun. 30, 2020

Inventory Disclosure [Abstract]

Inventories

Inventories consisted of the following:

	June 30, 2020		December 31, 2019
	(In millions)
Crude oil and natural gas liquids	$	204	$	92
Materials and supplies	156		169
Total Inventories	$	360	$	261

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Property Plant and Equipment (Tables)

6 Months Ended

Jun. 30, 2020

Property, Plant and Equipment [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 six months ended June 30, 2020 (in millions):

Balance at January 1, 2020	$	584
Additions to capitalized exploratory well costs pending the determination of proved reserves	70
Capitalized exploratory well costs charged to expense	(125)
Balance at June 30, 2020	$	529

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Revenue (Tables)

6 Months Ended

Jun. 30, 2020

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		Guyana		Malaysia & JDA		Denmark		Libya		E&P Total
	(In millions)
Three Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	254	$	31	$	1	$	14	$	—	$	300	$	—	$	—	$	300
Natural gas liquids revenue	43		—		—		—		—		43		—		—		43
Natural gas revenue	32		—		89		2		—		123		—		—		123
Sales of purchased oil and gas	143		—		—		—		—		143		—		—		143
Intercompany revenue	—		—		—		—		—		—		270		(270)		—
Total revenues from contracts with customers	472		31		90		16		—		609		270		(270)		609
Other operating revenues (a)	188		27		—		9		—		224		—		—		224
Total sales and other operating revenues	$	660	$	58	$	90	$	25	$	—	$	833	$	270	$	(270)	$	833
Three Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	762	$	—	$	24	$	51	$	130	$	967	$	—	$	—	$	967
Natural gas liquids revenue	48		—		—		—		—		48		—		—		48
Natural gas revenue	33		—		154		2		6		195		—		—		195
Sales of purchased oil and gas	439		—		—		—		22		461		—		—		461
Intercompany revenue	—		—		—		—		—		—		190		(190)		—
Total revenues from contracts with customers	1,282		—		178		53		158		1,671		190		(190)		1,671
Other operating revenues (a)	(11)		—		—		—		—		(11)		—		—		(11)
Total sales and other operating revenues	$	1,271	$	—	$	178	$	53	$	158	$	1,660	$	190	$	(190)	$	1,660
Six Months Ended June 30, 2020
Sales of our net production volumes:
Crude oil revenue	$	919	$	69	$	3	$	50	$	—	$	1,041	$	—	$	—	$	1,041
Natural gas liquids revenue	91		—		—		—		—		91		—		—		91
Natural gas revenue	70		—		228		4		2		304		—		—		304
Sales of purchased oil and gas	459		1		—		—		—		460		—		—		460
Intercompany revenue	—		—		—		—		—		—		561		(561)		—
Total revenues from contracts with customers	1,539		70		231		54		2		1,896		561		(561)		1,896
Other operating revenues (a)	243		33		1		14		—		291		—		—		291
Total sales and other operating revenues	$	1,782	$	103	$	232	$	68	$	2	$	2,187	$	561	$	(561)	$	2,187
Six Months Ended June 30, 2019
Sales of our net production volumes:
Crude oil revenue	$	1,444	$	—	$	45	$	67	$	221	$	1,777	$	—	$	—	$	1,777
Natural gas liquids revenue	116		—		—		—		—		116		—		—		116
Natural gas revenue	75		—		334		5		12		426		—		—		426
Sales of purchased oil and gas	865		—		—		—		44		909		—		—		909
Intercompany revenue	—		—		—		—		—		—		380		(380)		—
Total revenues from contracts with customers	2,500		—		379		72		277		3,228		380		(380)		3,228
Other operating revenues (a)	4		—		—		—		—		4		—		—		4
Total sales and other operating revenues	$	2,504	$	—	$	379	$	72	$	277	$	3,232	$	380	$	(380)	$	3,232

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

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Retirement Plans (Tables)

6 Months Ended

Jun. 30, 2020

Retirement Benefits [Abstract]

Components of Net Periodic Pension Cost

Components of net periodic pension cost consisted of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Service cost	$	14	$	11	$	28	$	21
Interest cost (a)	19		24		37		48
Expected return on plan assets (a)	(45)		(45)		(90)		(90)
Amortization of unrecognized net actuarial losses (a)	12		12		24		23
Pension (income) expense (a)	$	—	$	2	$	(1)	$	2

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three and six months ended June 30, 2020 was income of $14 million and $29 million, respectively, compared with income of $9 million and $19 million for the three and six months ended June 30, 2019, respectively.

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Weighted Average Common Shares (Tables)

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(In millions)
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net income (loss)	$	(263)	$	34	$	(2,629)	$	109
Less: Net income (loss) attributable to noncontrolling interests	57		40		124		83
Less: Preferred stock dividends	—		—		—		4
Net income (loss) attributable to Hess Corporation Common Stockholders	$	(320)	$	(6)	$	(2,753)	$	22
Weighted average number of common shares outstanding:
Basic	305.0		302.2		304.5		299.8
Effect of dilutive securities
Restricted common stock	—		—		—		0.9
Stock options	—		—		—		0.2
Performance share units	—		—		—		1.2
Diluted	305.0		302.2		304.5		302.1

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 June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
Restricted common stock	2,173,061	2,156,525	2,094,360	28,970
Stock options	4,429,642	4,894,731	4,239,533	2,920,944
Performance share units	992,166	1,858,050	1,144,261	32,831
Common shares from conversion of preferred stock	—	—	—	1,954,473

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Schedule of Financial Data by Operating Segment

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 June 30, 2020
Sales and Other Operating Revenues - Third parties	$	833	$	—	$	—	$	—	$	833
Intersegment Revenues	—		270		—		(270)		—
Sales and Other Operating Revenues	$	833	$	270	$	—	$	(270)	$	833
Net Income (Loss) attributable to Hess Corporation	$	(249)	$	51	$	(122)	$	—	$	(320)
Depreciation, Depletion and Amortization	470		39		—		—		509
Provision (Benefit) for Income Taxes	(11)		2		—		—		(9)
Capital Expenditures	428		79		—		—		507
For the Three Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	1,660	$	—	$	—	$	—	$	1,660
Intersegment Revenues	—		190		—		(190)		—
Sales and Other Operating Revenues	$	1,660	$	190	$	—	$	(190)	$	1,660
Net Income (Loss) attributable to Hess Corporation	$	68	$	35	$	(109)	$	—	$	(6)
Depreciation, Depletion and Amortization	459		35		—		—		494
Provision (Benefit) for Income Taxes	131		—		1		—		132
Capital Expenditures	625		69		—		—		694
For the Six Months Ended June 30, 2020
Sales and Other Operating Revenues - Third parties	$	2,187	$	—	$	—	$	—	$	2,187
Intersegment Revenues	—		561		—		(561)		—
Sales and Other Operating Revenues	$	2,187	$	561	$	—	$	(561)	$	2,187
Net Income (Loss) attributable to Hess Corporation	$	(2,620)	$	112	$	(245)	$	—	$	(2,753)
Depreciation, Depletion and Amortization	991		77		2		—		1,070
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(88)		4		(4)		—		(88)
Capital Expenditures	1,037		136		—		—		1,173
For the Six Months Ended June 30, 2019
Sales and Other Operating Revenues - Third parties	$	3,232	$	—	$	—	$	—	$	3,232
Intersegment Revenues	—		380		—		(380)		—
Sales and Other Operating Revenues	$	3,232	$	380	$	—	$	(380)	$	3,232
Net Income (Loss) attributable to Hess Corporation	$	177	$	72	$	(223)	$	—	$	26
Depreciation, Depletion and Amortization	923		69		—		—		992
Provision (Benefit) for Income Taxes	226		—		—		—		226
Capital Expenditures	1,140		196		—		—		1,336

Identifiable assets by operating segment were as follows:

	June 30, 2020		December 31, 2019
	(In millions)
Exploration and Production	$	14,267	$	16,790
Midstream	3,550		3,499
Corporate, Interest and Other	1,729		1,493
Total	$	19,546	$	21,782

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Financial Risk Management Activities (Tables)

6 Months Ended

Jun. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Financial Risk Management Derivative Contracts

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

	June 30, 2020		December 31, 2019
	(In millions)
Commodity - crude oil put options (millions of barrels)	27.6		54.9
Foreign exchange forwards	$	74	$	90
Interest rate swaps	$	100	$	100

Gross and Net Fair Values of Financial Risk Management Derivative Instruments

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

	Assets		Liabilities
	(In millions)
June 30, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	450	$	—
Interest rate swaps - Other assets (noncurrent)	6		—
Total derivative contracts designated as hedging instruments	456		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts receivable - Joint venture and other	2		—
Total derivative contracts not designated as hedging instruments	2		—
Gross fair value of derivative contracts	458		—
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	458	$	—
December 31, 2019
Derivative Contracts Designated as Hedging Instruments:
Crude oil derivative contracts	$	125	$	—
Interest rate swaps - Other assets (noncurrent)	1		—
Total derivative contracts designated as hedging instruments	126		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards - Accounts payable	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	126		(1)
Master netting arrangements	—		—
Net Fair Value of Derivative Contracts	$	126	$	(1)

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Inventories - Inventories (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 204	$ 92
Materials and supplies	156	169
Total Inventories	$ 360	$ 261

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Inventories - Additional Information (Detail) barrelOfOil in Millions, $ in Millions	3 Months Ended	4 Months Ended	6 Months Ended
	Jun. 30, 2020 USD ($) vlcc barrelOfOil	Aug. 31, 2020 barrelOfOil	Jun. 30, 2020 USD ($) vlcc	Dec. 31, 2019 USD ($)
Inventory Disclosure [Abstract]
Charges related to inventories			$ 53
Charges related to inventories, after income taxes			$ 52
Inventory [Line Items]
Number of very large crude carriers | vlcc	3		3
Crude oil in very large crude carriers | barrelOfOil	3.7
Cost of crude oil	$ 204		$ 204	$ 92
Very Large Crude Carriers (VLCCs)
Inventory [Line Items]
Cost of crude oil	$ 113		$ 113
Forecast | Subsequent Event
Inventory [Line Items]
Crude oil in very large crude carriers | barrelOfOil		6.0

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Property Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($)
Property, Plant and Equipment [Abstract]
Beginning balance	$ 584
Additions to capitalized exploratory well costs pending the determination of proved reserves	70
Capitalized exploratory well costs charged to expense	(125)
Ending balance	$ 529

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Property Plant and Equipment - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($) well
Capitalized Exploratory Well Costs [Line Items]
Previously capitalized well cost expensed	$ 125
Capitalized exploratory well costs that have been capitalized for period greater than one year	360
Northern Portion of Shenzi Field, Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Previously capitalized well cost expensed	$ 125
Project interest percentage	28.00%
Oldfield-1 Exploration Well in Gulf of Mexico
Capitalized Exploratory Well Costs [Line Items]
Well costs incurred and expensed	$ 10
Successful Exploration Wells on the Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	30.00%
Capitalized well costs percentage	80.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Project interest percentage	50.00%
Capitalized well costs percentage	10.00%
Number of successful exploration wells drilled | well	3
North Malay Basin, Offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	10.00%
Project interest percentage	50.00%
Number of successful exploration wells drilled | well	5

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Hess Midstream LP (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Variable Interest Entity [Line Items]
Liabilities	$ 12,180	$ 12,076
Cash and cash equivalents	1,646	1,545
Property, plant and equipment, net	14,825	16,814
Hess Midstream LP | Variable Interest Entity
Variable Interest Entity [Line Items]
Liabilities	1,972	1,941
Cash and cash equivalents	3	3
Property, plant and equipment, net	$ 3,069	$ 3,010

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Debt (Detail)	6 Months Ended
	Jun. 30, 2020 USD ($)
Debt Disclosure [Abstract]
Line of credit facility, maximum borrowing capacity	$ 1,000,000,000.0
Loan agreement term (in years)	3 years
Maturity date of loan agreement	Mar. 16, 2023
Debt instrument covenant, ratio	65.00%
Long-term line of credit	$ 1,000,000,000.0
London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Interest rate, applicable margin	2.25%
Annual increase in applicable margin on interest rate	0.25%

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Revenue (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 609	$ 1,671	$ 1,896	$ 3,228
Other operating revenues	224	(11)	291	4
Total sales and other operating revenues	833	1,660	2,187	3,232
Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	300	967	1,041	1,777
Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	43	48	91	116
Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	123	195	304	426
Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	461	460	909
Exploration and Production
Disaggregation of Revenue [Line Items]
Total sales and other operating revenues	833	1,660	2,187	3,232
Exploration and Production | Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	300	967	1,041	1,777
Exploration and Production | Crude oil revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	254	762	919	1,444
Exploration and Production | Crude oil revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	31	0	69	0
Exploration and Production | Crude oil revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	24	3	45
Exploration and Production | Crude oil revenue | Denmark
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	14	51	50	67
Exploration and Production | Crude oil revenue | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	130	0	221
Exploration and Production | Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	43	48	91	116
Exploration and Production | Natural gas liquids revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	43	48	91	116
Exploration and Production | Natural gas liquids revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Exploration and Production | Natural gas liquids revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Exploration and Production | Natural gas liquids revenue | Denmark
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Exploration and Production | Natural gas liquids revenue | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Exploration and Production | Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	123	195	304	426
Exploration and Production | Natural gas revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	32	33	70	75
Exploration and Production | Natural gas revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Exploration and Production | Natural gas revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	89	154	228	334
Exploration and Production | Natural gas revenue | Denmark
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2	2	4	5
Exploration and Production | Natural gas revenue | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	6	2	12
Exploration and Production | Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	461	460	909
Exploration and Production | Sales of purchased oil and gas | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	439	459	865
Exploration and Production | Sales of purchased oil and gas | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	1	0
Exploration and Production | Sales of purchased oil and gas | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
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
Exploration and Production | Sales of purchased oil and gas | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	22	0	44
Midstream
Disaggregation of Revenue [Line Items]
Total sales and other operating revenues	0	0	0	0
Midstream | Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Midstream | Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Midstream | Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Midstream | Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Exploration and Production
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	609	1,671	1,896	3,228
Other operating revenues	224	(11)	291	4
Total sales and other operating revenues	833	1,660	2,187	3,232
Operating Segments | Exploration and Production | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	472	1,282	1,539	2,500
Other operating revenues	188	(11)	243	4
Total sales and other operating revenues	660	1,271	1,782	2,504
Operating Segments | Exploration and Production | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	31	0	70	0
Other operating revenues	27	0	33	0
Total sales and other operating revenues	58	0	103	0
Operating Segments | Exploration and Production | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	90	178	231	379
Other operating revenues	0	0	1	0
Total sales and other operating revenues	90	178	232	379
Operating Segments | Exploration and Production | Denmark
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	16	53	54	72
Other operating revenues	9	0	14	0
Total sales and other operating revenues	25	53	68	72
Operating Segments | Exploration and Production | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	158	2	277
Other operating revenues	0	0	0	0
Total sales and other operating revenues	0	158	2	277
Operating Segments | Midstream
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	270	190	561	380
Other operating revenues	0	0	0	0
Total sales and other operating revenues	270	190	561	380
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(270)	(190)	(561)	(380)
Other operating revenues	0	0	0	0
Total sales and other operating revenues	(270)	(190)	(561)	(380)
Eliminations | Exploration and Production
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Total sales and other operating revenues	0	0	0	0
Eliminations | Exploration and Production | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Exploration and Production | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Exploration and Production | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Exploration and Production | Denmark
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Exploration and Production | Libya
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Midstream
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	270	190	561	380
Total sales and other operating revenues	$ 270	$ 190	$ 561	$ 380

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Impairment (Detail) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2020 USD ($)	Mar. 31, 2020 USD ($) $ / bbl	Jun. 30, 2019 USD ($)	Jun. 30, 2020 USD ($)	Jun. 30, 2019 USD ($)
Impairments [Line Items]
Impairment charge, pre-tax	$ 0		$ 0	$ 2,126	$ 0
Oil and Gas Properties
Impairments [Line Items]
Fair value of estimated impairment charges determined using internal projected discounted cash flows		$ 1,050
Weighted average crude oil benchmark price for impaired assets (US dollar per barrel) | $ / bbl		48.82
Fair value of estimated impairment charges discount rate		10.00%
Oil and Gas Properties | West Texas Intermediate
Impairments [Line Items]
Impairment charge, future flat price (US dollar per barrel) | $ / bbl		50
Oil and Gas Properties | Brent
Impairments [Line Items]
Impairment charge, future flat price (US dollar per barrel) | $ / bbl		55
Oil and Gas Properties | North Malay Basin Field | Malaysia
Impairments [Line Items]
Impairment charge, pre-tax				755
Impairment charge, after income taxes				755
Oil and Gas Properties | South Arne Field | Denmark
Impairments [Line Items]
Impairment charge, pre-tax				670
Impairment charge, after income taxes				594
Oil and Gas Properties | Stampede Field | Gulf of Mexico
Impairments [Line Items]
Impairment charge, pre-tax				410
Impairment charge, after income taxes				410
Oil and Gas Properties | Tubular Bells Field | Gulf of Mexico
Impairments [Line Items]
Impairment charge, pre-tax				270
Impairment charge, after income taxes				$ 270
Other Assets
Impairments [Line Items]
Impairment charge, pre-tax		$ 21
Impairment charge, after income taxes		$ 20

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Retirement Plans - Components of Net Periodic Pension Cost (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Retirement Benefits [Abstract]
Service cost	$ 14	$ 11	$ 28	$ 21
Interest cost	19	24	37	48
Expected return on plan assets	(45)	(45)	(90)	(90)
Amortization of unrecognized net actuarial losses	12	12	24	23
Pension (income) expense	0	2	(1)	2
Net non-service pension (income) costs included in Other, net	$ (14)	$ (9)	$ (29)	$ (19)

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Retirement Plans - Additional Information (Detail) $ in Millions	Jun. 30, 2020 USD ($)
Retirement Benefits [Abstract]
Corporation's estimated contribution for funded pension plans in 2020	$ 2

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Weighted Average Common Shares - Net Income (Loss) and Weighted Average Number of Common Shares Used in Computation of Basic and Diluted Earnings Per Share (Detail) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Net income (loss) attributable to Hess Corporation Common Stockholders:
Net income (loss)	$ (263)	$ 34	$ (2,629)	$ 109
Less: Net income (loss) attributable to noncontrolling interests	57	40	124	83
Less: Preferred stock dividends	0	0	0	4
Net income (loss) attributable to Hess Corporation Common Stockholders	$ (320)	$ (6)	$ (2,753)	$ 22
Weighted average number of common shares outstanding:
Basic (in shares)	305.0	302.2	304.5	299.8
Diluted (in shares)	305.0	302.2	304.5	302.1
Restricted common stock
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.0	0.0	0.0	0.9
Stock options
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.0	0.0	0.0	0.2
Performance share units
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.0	0.0	0.0	1.2

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Weighted Average Common Shares - Antidilutive Shares Excluded from Computation of Diluted Shares (Detail) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Restricted common stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	2,173,061	2,156,525	2,094,360	28,970
Stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	4,429,642	4,894,731	4,239,533	2,920,944
Performance share units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	992,166	1,858,050	1,144,261	32,831
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 (in shares)	0	0	0	1,954,473

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Weighted Average Common Shares - Additional Information (Detail) - shares	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Shares granted, restricted stock (in shares)	1,120,356	945,009
Shares granted, performance share units (in shares)	307,999	234,866
Shares granted, stock options (in shares)	686,639	526,968

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Guarantees and Contingencies (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($) case
MTBE Cases
Loss Contingencies [Line Items]
Total number of remaining active cases filed | case	3
Lower Passaic River
Loss Contingencies [Line Items]
Estimated remediation cost	$ 1,380
Gowanus Canal Superfund Site
Loss Contingencies [Line Items]
Estimated remediation cost	$ 506

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Segment Information - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020 segment
Segment Reporting [Abstract]
Number of operating segments	2

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Segment Information - Financial Data by Operating Segment (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 833	$ 1,660	$ 2,187	$ 3,232
Net Income (Loss) attributable to Hess Corporation	(320)	(6)	(2,753)	26
Depreciation, depletion and amortization	509	494	1,070	992
Impairment			2,126
Provision (benefit) for income taxes	(9)	132	(88)	226
Capital Expenditures	507	694	1,173	1,336
Assets	19,546		19,546		$ 21,782
Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	833	1,660	2,187	3,232
Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0	0	0
Operating Segments | Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	833	1,660	2,187	3,232
Net Income (Loss) attributable to Hess Corporation	(249)	68	(2,620)	177
Depreciation, depletion and amortization	470	459	991	923
Impairment			2,126
Provision (benefit) for income taxes	(11)	131	(88)	226
Capital Expenditures	428	625	1,037	1,140
Assets	14,267		14,267		16,790
Operating Segments | Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	270	190	561	380
Net Income (Loss) attributable to Hess Corporation	51	35	112	72
Depreciation, depletion and amortization	39	35	77	69
Impairment			0
Provision (benefit) for income taxes	2	0	4	0
Capital Expenditures	79	69	136	196
Assets	3,550		3,550		3,499
Corporate, Interest and Other
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	(122)	(109)	(245)	(223)
Depreciation, depletion and amortization	0	0	2	0
Impairment			0
Provision (benefit) for income taxes	0	1	(4)	0
Capital Expenditures	0	0	0	0
Assets	1,729		1,729		$ 1,493
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	(270)	(190)	(561)	(380)
Net Income (Loss) attributable to Hess Corporation	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment			0
Provision (benefit) for income taxes	0	0	0	0
Capital Expenditures	0	0	0	0
Eliminations | Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0	0	0
Eliminations | Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 270	$ 190	$ 561	$ 380

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Financial Risk Management Activities - Notional Amounts of Outstanding Financial Risk Management Derivative Contracts (Detail) MMBbls in Millions	Jun. 30, 2020 USD ($) MMBbls	Dec. 31, 2019 USD ($) MMBbls
Commodity derivative contracts
Derivative [Line Items]
Commodity - crude oil | MMBbls	27.6	54.9
Foreign exchange forwards
Derivative [Line Items]
Outstanding gross notional amount	$ 74,000,000	$ 90,000,000
Interest rate swaps | Designated as Fair Value Hedges
Derivative [Line Items]
Outstanding gross notional amount	$ 100,000,000	$ 100,000,000

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Financial Risk Management Activities - Additional Information (Detail) - Commodity derivative contracts MMBbls in Millions	Jun. 30, 2020 bbl / d MMBbls $ / bbl	Dec. 31, 2019 MMBbls
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount of crude oil | MMBbls	27.6	54.9
West Texas Intermediate | Designated as Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Average monthly floor price (US dollar per barrel) | $ / bbl	55
Notional amount of crude oil | bbl / d	130,000
Brent | Designated as Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Average monthly floor price (US dollar per barrel) | $ / bbl	60
Notional amount of crude oil | bbl / d	20,000

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Financial Risk Management Activities - Gross and Net Fair Values (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 458	$ 126
Master netting arrangements	0	0
Assets - Net Fair Value of Derivative Contracts	458	126
Liabilities - Gross fair value of derivative contracts	0	(1)
Master netting arrangements	0	0
Liabilities - Net Fair Value of Derivative Contracts	0	(1)
Derivative Contracts Designated as Hedging Instruments:
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	456	126
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments: | Commodity derivative contracts
Derivatives, Fair Value [Line Items]
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments: | Commodity derivative contracts | Crude Oil Derivative Contracts
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	450	125
Derivative Contracts Designated as Hedging Instruments: | Interest rate swaps
Derivatives, Fair Value [Line Items]
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments: | Interest rate swaps | Other Assets
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	6	1
Derivative Contracts Not Designated as Hedging Instruments:
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	2	0
Liabilities - Gross fair value of derivative contracts	0	(1)
Derivative Contracts Not Designated as Hedging Instruments: | Foreign exchange forwards | Accounts Receivable - Joint Venture and Other
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	2	0
Derivative Contracts Not Designated as Hedging Instruments: | Foreign exchange forwards | Accounts Payable
Derivatives, Fair Value [Line Items]
Liabilities - Gross fair value of derivative contracts	$ 0	$ (1)

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Financial Risk Management Activities - Derivative Contracts - Additional Information (Detail) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
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
Foreign exchange forwards
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding gross notional amount	74,000,000		74,000,000		90,000,000
Derivative Contracts Designated as Hedging Instruments: | Commodity derivative contracts
Derivative Instruments, Gain (Loss) [Line Items]
Increased (decreased) sales and other operating revenue	228,000,000	$ (14,000,000)	292,000,000	$ 1,000,000
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings during the remainder of 2020			386,000,000
Derivative Contracts Designated as Hedging Instruments: | 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 in derivative asset (decrease in derivative liability)	1,000,000	(2,000,000)	6,000,000	(3,000,000)
Derivative Contracts Not Designated as Hedging Instruments: | Foreign exchange forwards
Derivative Instruments, Gain (Loss) [Line Items]
Foreign exchange gains (losses) reported in Other, net in the Statement of Consolidated Income	(2,000,000)	(2,000,000)	(3,000,000)	3,000,000
Net gains (losses) on foreign exchange contracts not designated as hedging instruments	$ 1,000,000	$ 1,000,000	$ 3,000,000	$ 1,000,000

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Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Jun. 30, 2020 USD ($)
Fair Value Disclosures [Abstract]
Long-term debt	$ 8,210
Long-term debt, fair value	$ 8,736