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 March 31, 2021

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 March 31, 2021, there were 308,436,780 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 March 31, 2021, and December 31, 2020	2
	Statement of Consolidated Income for the Three Months Ended March 31, 2021, and 2020	3
	Statement of Consolidated Comprehensive Income for the Three Months Ended March 31, 2021, and 2020	4
	Statement of Consolidated Cash Flows for the Three Months Ended March 31, 2021, and 2020	5
	Statement of Consolidated Equity for the Three Months Ended March 31, 2021, and 2020	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 - Accrued Liabilities	8
	Note 6 - Revenue	9
	Note 7 - Impairment	9
	Note 8 - Retirement Plans	10
	Note 9 - Weighted Average Common Shares	10
	Note 10 - Guarantees and Contingencies	11
	Note 11 - Segment Information	12
	Note 12 - Financial Risk Management Activities	13
	Note 13 - Subsequent Events	15
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
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)

	March 31, 2021		December 31, 2020
	(In millions, except share amounts)
Assets
Current Assets:
Cash and cash equivalents	$	1,866	$	1,739
Accounts receivable:
From contracts with customers	860		710
Joint venture and other	151		150
Inventories	219		378
Assets held for sale	229		—
Other current assets	197		104
Total current assets	3,522		3,081
Property, plant and equipment:
Total — at cost	30,642		30,519
Less: Reserves for depreciation, depletion, amortization and lease impairment	16,779		16,404
Property, plant and equipment — net	13,863		14,115
Operating lease right-of-use assets — net	386		426
Finance lease right-of-use assets — net	161		168
Goodwill	360		360
Deferred income taxes	41		59
Other assets	618		612
Total Assets	$	18,951	$	18,821
Liabilities
Current Liabilities:
Accounts payable	$	172	$	200
Accrued liabilities	1,254		1,251
Taxes payable	168		81
Current maturities of long-term debt	13		10
Current portion of operating and finance lease obligations	83		81
Total current liabilities	1,690		1,623
Long-term debt	8,273		8,286
Long-term operating lease obligations	437		478
Long-term finance lease obligations	215		220
Deferred income taxes	324		342
Asset retirement obligations	758		894
Other liabilities and deferred credits	611		643
Total Liabilities	12,308		12,486
Equity
Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized — 600,000,000 shares
Issued — 308,436,780 shares (2020: 306,980,092)	308		307
Capital in excess of par value	5,779		5,684
Retained earnings	305		130
Accumulated other comprehensive income (loss)	(776)		(755)
Total Hess Corporation stockholders’ equity	5,616		5,366
Noncontrolling interests	1,027		969
Total Equity	6,643		6,335
Total Liabilities and Equity	$	18,951	$	18,821

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 March 31,
	2021		2020
	(In millions, except per share amounts)
Revenues and Non-Operating Income
Sales and other operating revenues	$	1,898	$	1,354
Other, net	21		15
Total revenues and non-operating income	1,919		1,369
Costs and Expenses
Marketing, including purchased oil and gas	518		378
Operating costs and expenses	265		303
Production and severance taxes	37		42
Exploration expenses, including dry holes and lease impairment	33		189
General and administrative expenses	94		102
Interest expense	117		113
Depreciation, depletion and amortization	396		561
Impairment	—		2,126
Total costs and expenses	1,460		3,814
Income (Loss) Before Income Taxes	459		(2,445)
Provision (benefit) for income taxes	123		(79)
Net Income (Loss)	336		(2,366)
Less: Net income (loss) attributable to noncontrolling interests	84		67
Net Income (Loss) Attributable to Hess Corporation	$	252	$	(2,433)
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$	0.82	$	(8.00)
Diluted	$	0.82	$	(8.00)
Weighted Average Number of Common Shares Outstanding:
Basic	305.8		304.0
Diluted	307.8		304.0
Common Stock Dividends Per Share	$	0.25	$	0.25

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 March 31,
	2021		2020
	(In millions)
Net Income (Loss)	$	336	$	(2,366)
Other Comprehensive Income (Loss):
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	51		(64)
Income taxes on effect of hedge (gains) losses reclassified to income	—		—
Net effect of hedge (gains) losses reclassified to income	51		(64)
Change in fair value of cash flow hedges	(102)		990
Income taxes on change in fair value of cash flow hedges	—		—
Net change in fair value of cash flow hedges	(102)		990
Change in derivatives designated as cash flow hedges, after taxes	(51)		926
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	14		—
Income taxes on actuarial changes in plan liabilities	—		—
(Increase) reduction in unrecognized actuarial losses, net	14		—
Amortization of net actuarial losses	16		12
Income taxes on amortization of net actuarial losses	—		—
Net effect of amortization of net actuarial losses	16		12
Change in pension and other postretirement plans, after taxes	30		12
Other Comprehensive Income (Loss)	(21)		938
Comprehensive Income (Loss)	315		(1,428)
Less: Comprehensive income (loss) attributable to noncontrolling interests	84		67
Comprehensive Income (Loss) Attributable to Hess Corporation	$	231	$	(1,495)

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)

	Three Months Ended March 31,
	2021		2020
	(In millions)
Cash Flows From Operating Activities
Net income (loss)	$	336	$	(2,366)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	396		561
Impairment	—		2,126
Exploratory dry hole costs	—		135
Exploration lease and other impairment	4		32
Pension settlement loss	1		—
Stock compensation expense	25		29
Noncash (gains) losses on commodity derivatives, net	24		70
Provision (benefit) for deferred income taxes and other tax accruals	29		(85)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(329)		258
(Increase) decrease in inventories	159		31
Increase (decrease) in accounts payable and accrued liabilities	(127)		(263)
Increase (decrease) in taxes payable	87		(63)
Changes in other operating assets and liabilities	(14)		(20)
Net cash provided by (used in) operating activities	591		445
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(358)		(740)
Additions to property, plant and equipment - Midstream	(27)		(78)
Net cash provided by (used in) investing activities	(385)		(818)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	(10)		60
Debt with maturities of greater than 90 days:
Borrowings	—		1,000
Repayments	(3)		—
Proceeds from sale of Class A shares of Hess Midstream LP	70		—
Payments on finance lease obligations	(2)		(1)
Cash dividends paid	(80)		(81)
Noncontrolling interests, net	(67)		(63)
Other, net	13		(7)
Net cash provided by (used in) financing activities	(79)		908
Net Increase (Decrease) in Cash and Cash Equivalents	127		535
Cash and Cash Equivalents at Beginning of Year	1,739		1,545
Cash and Cash Equivalents at End of Period	$	1,866	$	2,080

See accompanying Notes to Consolidated Financial Statements.

5

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED EQUITY (UNAUDITED)

		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 March 31, 2021
Balance at January 1, 2021		$	307	$	5,684	$	130	$	(755)	$	5,366	$	969	$	6,335
Net income (loss)		—		—		252		—		252		84		336
Other comprehensive income (loss)		—		—		—		(21)		(21)		—		(21)
Share-based compensation		1		39		—		—		40		—		40
Dividends on common stock		—		—		(77)		—		(77)		—		(77)
Sale of Class A shares of Hess Midstream LP		—		56		—		—		56		41		97
Noncontrolling interests, net		—		—		—		—		—		(67)		(67)
Balance at March 31, 2021		$	308	$	5,779	$	305	$	(776)	$	5,616	$	1,027	$	6,643
For the Three Months Ended March 31, 2020
Balance at January 1, 2020		$	305	$	5,591	$	3,535	$	(699)	$	8,732	$	974	$	9,706
Net income (loss)		—		—		(2,433)		—		(2,433)		67		(2,366)
Other comprehensive income (loss)		—		—		—		938		938		—		938
Share-based compensation		2		42		(5)		—		39		—		39
Dividends on common stock		—		—		(76)		—		(76)		—		(76)
Noncontrolling interests, net		—		—		—		—		—		(63)		(63)
Balance at March 31, 2020		$	307	$	5,633	$	1,021	$	239	$	7,200	$	978	$	8,178

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 March 31, 2021 and December 31, 2020, the consolidated results of operations for the three months ended March 31, 2021 and 2020, and consolidated cash flows for the three months ended March 31, 2021 and 2020.  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, 2020.

 2.  Inventories

Inventories consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Crude oil and natural gas liquids	$	46	$	226
Materials and supplies	173		152
Total Inventories	$	219	$	378

At December 31, 2020, crude oil inventories included $164 million associated with the cost of 4.2 million barrels of crude oil transported and stored on two chartered very large crude carriers (VLCCs) for sale in Asian markets. The two VLCC cargos were sold in the first quarter of 2021.

In the first quarter of 2020, we recognized charges of $53 million ($52 million after income taxes) in Marketing, including purchased oil and gas to reflect crude oil inventories at net realizable value.

3.  Property, Plant and Equipment

Assets Held for Sale:

In March 2021, we entered into an agreement to sell our interests in Denmark for total consideration of $150 million with an effective date of January 1, 2021. At March 31, 2021, property, plant and equipment and operating lease right-of-use assets totaling $229 million, and asset retirement obligations and operating lease liabilities totaling $138 million, associated with our interests in Denmark were presented as Assets held for sale and as liabilities held for sale within Accrued Liabilities, respectively, in our Consolidated Balance Sheet.

Capitalized Exploratory Well Costs:  

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the three months ended March 31, 2021 (in millions):

Balance at January 1, 2021	$	459
Additions to capitalized exploratory well costs pending the determination of proved reserves	17
Balance at March 31, 2021	$	476

Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $375 million at March 31, 2021 and primarily related to:  

Guyana: Approximately 85% 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 and is conducting pre-development planning for additional phases of development beyond the three previously sanctioned development projects on the Block.

7

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 5% 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 one successful exploration well.  Subsurface evaluation and pre-development studies are ongoing.

4.  Hess Midstream LP

In March 2021, the Corporation received net proceeds of $70 million from the public offering of 3,450,000 Hess-owned Class A shares in Hess Midstream LP. The transaction resulted in an increase in Capital in Excess of Par of $56 million and Noncontrolling Interests of $41 million including $14 million from the change in ownership and $27 million from the recognition of a deferred tax asset due to an increase in tax basis of Hess Midstream LP's investment in Hess Midstream Operations LP. After giving effect to this transaction, the Corporation owns an approximate 46% interest in Hess Midstream LP, on a consolidated basis.

At March 31, 2021 Hess Midstream LP, a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling $1,984 million (December 31, 2020: $2,026 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream LP assets available to settle the obligations of Hess Midstream LP include cash and cash equivalents totaling $2 million (December 31, 2020: $3 million), property, plant and equipment with a carrying value of $3,095 million (December 31, 2020: $3,111 million) and an equity-method investment of $104 million (December 31, 2020: $108 million) in the Little Missouri 4 gas processing plant.

5.  Accrued Liabilities

Accrued Liabilities consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Accrued capital expenditures	$	263	$	345
Accrued operating and marketing expenditures	263		325
Accrued payments to royalty and working interest owners	227		170
Liabilities held for sale	138		—
Accrued interest on debt	96		126
Accrued compensation and benefits	93		117
Current portion of asset retirement obligations	156		105
Other accruals	18		63
Total Accrued Liabilities	$	1,254	$	1,251

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		Other (a)		E&P Total
	(In millions)
Three Months Ended March 31, 2021
Sales of our net production volumes:
Crude oil revenue	$	885	$	181	$	22	$	116	$	1,204	$	—	$	—	$	1,204
Natural gas liquids revenue	143		—		—		—		143		—		—		143
Natural gas revenue	113		—		163		3		279		—		—		279
Sales of purchased oil and gas	298		4		—		19		321		—		—		321
Intercompany revenue	—		—		—		—		—		289		(289)		—
Total revenues from contracts with customers	1,439		185		185		138		1,947		289		(289)		1,947
Other operating revenues (b)	(41)		(4)		—		(4)		(49)		—		—		(49)
Total sales and other operating revenues	$	1,398	$	181	$	185	$	134	$	1,898	$	289	$	(289)	$	1,898
Three Months Ended March 31, 2020
Sales of our net production volumes:
Crude oil revenue	$	656	$	38	$	2	$	36	$	732	$	—	$	—	$	732
Natural gas liquids revenue	49		—		—		—		49		—		—		49
Natural gas revenue	38		—		139		4		181		—		—		181
Sales of purchased oil and gas	324		1		—		—		325		—		—		325
Intercompany revenue	—		—		—		—		—		291		(291)		—
Total revenues from contracts with customers	1,067		39		141		40		1,287		291		(291)		1,287
Other operating revenues (b)	55		6		1		5		67		—		—		67
Total sales and other operating revenues	$	1,122	$	45	$	142	$	45	$	1,354	$	291	$	(291)	$	1,354

(a)Other includes our interests in Denmark and Libya.

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

There have been no significant changes to contracts with customers or composition thereof during the three months ended March 31, 2021.  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.

7.  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 and Tubular Bells fields 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.

9

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

8. Retirement Plans

Components of net periodic pension cost consisted of the following:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Service cost	$	14	$	14
Interest cost (a)	14		18
Expected return on plan assets (a)	(50)		(45)
Amortization of unrecognized net actuarial losses (a)	15		12
Settlement loss (a)	1		—
Pension (income) expense (a)	$	(6)	$	(1)

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three months ended March 31, 2021 was income of $20 million (2020: income of $15 million).

In 2021, we expect to contribute approximately $4 million to our funded pension plans.

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 March 31,
	2021		2020
	(In millions)
Net income (loss) attributable to Hess Corporation:
Net income (loss)	$	336	$	(2,366)
Less: Net income (loss) attributable to noncontrolling interests	84		67
Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)
Weighted average number of common shares outstanding:
Basic	305.8		304.0
Effect of dilutive securities
Restricted common stock	0.8		—
Stock options	0.4		—
Performance share units	0.8		—
Diluted	307.8		304.0

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

	Three Months Ended March 31,
	2021	2020
Restricted common stock	189,000	2,015,659
Stock options	1,164,214	4,086,340
Performance share units	36,134	1,296,356

During the three months ended March 31, 2021, we granted 695,832 shares of restricted stock (2020: 1,117,009), 319,295 stock options (2020: 686,639), and 205,155 performance share units (2020: 307,999).

10

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 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 began in the fourth quarter of 2020. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us, and the costs will continue to be allocated amongst the parties, as they were for the Remedial Design.

From time to time, we are involved in other judicial and administrative proceedings relating to environmental matters. 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

11

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

material. Beginning in 2017, certain states, municipalities and private associations in California, Delaware, Maryland, Rhode Island and South Carolina separately filed lawsuits against oil, gas and coal producers, including us, for alleged damages purportedly caused by climate change. These proceedings include claims for monetary damages and injunctive relief. Beginning in 2013, various parishes in Louisiana filed suit against approximately 100 oil and gas companies, including us, alleging that the companies’ operations and activities in certain fields violated the State and Local Coastal Resource Management Act of 1978, as amended, and caused contamination, subsidence and other environmental damages to land and water bodies located in the coastal zone of Louisiana. The plaintiffs seek, among other things, the payment of the costs necessary to clear, re-vegetate and otherwise restore the allegedly impacted areas. The ultimate impact of such climate and other aforementioned environmental 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.

We are also involved in other judicial and administrative proceedings from time to time in addition to the matters described above, including claims related to post-production deductions from royalty payments. 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.

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 March 31, 2021
Sales and Other Operating Revenues - Third parties	$	1,898	$	—	$	—	$	—	$	1,898
Intersegment Revenues	—		289		—		(289)		—
Sales and Other Operating Revenues	$	1,898	$	289	$	—	$	(289)	$	1,898
Net Income (Loss) attributable to Hess Corporation	$	308	$	75	$	(131)	$	—	$	252
Depreciation, Depletion and Amortization	355		40		1		—		396
Provision (Benefit) for Income Taxes	120		3		—		—		123
Capital Expenditures	280		23		—		—		303
For the Three Months Ended March 31, 2020
Sales and Other Operating Revenues - Third parties	$	1,354	$	—	$	—	$	—	$	1,354
Intersegment Revenues	—		291		—		(291)		—
Sales and Other Operating Revenues	$	1,354	$	291	$	—	$	(291)	$	1,354
Net Income (Loss) attributable to Hess Corporation	$	(2,371)	$	61	$	(123)	$	—	$	(2,433)
Depreciation, Depletion and Amortization	521		38		2		—		561
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(77)		2		(4)		—		(79)
Capital Expenditures	609		57		—		—		666

12

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Identifiable assets by operating segment were as follows:

	March 31, 2021		December 31, 2020
	(In millions)
Exploration and Production	$	13,764	$	13,688
Midstream	3,586		3,599
Corporate, Interest and Other	1,601		1,534
Total	$	18,951	$	18,821

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. 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 or establish a floor price for a portion of our crude oil or natural gas production. Swaps may also be used to fix the difference between current selling prices and forward selling prices in periods of contango for crude oil production that will be stored and sold in the future. Forward contracts may also be used to purchase certain currencies in which we conduct business with the intent of reducing exposure to foreign currency fluctuations. At March 31, 2021, these forward contracts relate to the British Pound, Danish Krone, Canadian Dollar and Malaysian Ringgit. 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:

	March 31, 2021		December 31, 2020
	(In millions)
Commodity - crude oil put options (millions of barrels)	41.3		27.4
Foreign exchange forwards	$	121	$	163
Interest rate swaps	$	100	$	100

As of March 31, 2021, we have purchased West Texas Intermediate (WTI) put options of 120,000 barrels of oil per day (bopd) with an average monthly floor price of $55 per barrel and Brent put options of 30,000 bopd with an average monthly floor price of $60 per barrel for the remainder of 2021.

13

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

The table below reflects the fair values of risk management derivative instruments.

	Assets		Liabilities
	(In millions)
March 31, 2021
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	154	$	—
Interest rate swaps	4		—
Total derivative contracts designated as hedging instruments	158		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(2)
Total derivative contracts not designated as hedging instruments	—		(2)
Gross fair value of derivative contracts	158		(2)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	158	$	(2)
December 31, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	64	$	—
Crude oil swaps	—		(54)
Interest rate swaps	5		—
Total derivative contracts designated as hedging instruments	69		(54)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	69		(55)
Gross amounts offset in the Consolidated Balance Sheet	(13)		13
Net Amounts Presented in the Consolidated Balance Sheet	$	56	$	(42)

During the first quarter of 2021, we completed the sale of 4.2 million barrels of Bakken crude oil transported and stored on two VLCCs during 2020 for sale in Asian markets. We recognized net losses of $4 million from crude oil hedging contracts associated with the VLCC volumes in the first quarter of 2021.

The fair value of our crude oil put options and crude oil swaps is presented within Other current assets and Accrued liabilities, respectively, in our Consolidated Balance Sheet. The fair value of our interest rate swaps is presented within Other assets in our Consolidated Balance Sheet. The fair value of our foreign exchange forwards is presented within Accrued liabilities in our Consolidated Balance Sheet. 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 decreased Sales and other operating revenues by $51 million in the first quarter of 2021, including hedge contracts associated with the VLCC transactions, and increased Sales and other operating revenues by $64 million in the first quarter of 2020. At March 31, 2021, pre-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding crude oil price hedging contracts were $47 million, all of which will be reclassified into earnings during the remainder of 2021 as the originally hedged crude oil sales are recognized in earnings.

Interest rate swaps designated as fair value hedges:  At March 31, 2021 and December 31, 2020, 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 months ended March 31, 2021, the change in fair value of interest rate swaps was a decrease in the asset of $1 million (2020 Q1: increase in the asset of $5 million) 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 $1 million in the three months ended March 31, 2021 (2020 Q1: $1 million loss).  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 losses of $1 million in the three months ended March 31, 2021 (2020 Q1: $2 million gain).

14

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Fair Value Measurement:

At March 31, 2021, our total long-term debt, which was substantially comprised of fixed rate debt instruments, had a carrying value of $8,286 million and a fair value of $9,381 million, based on Level 2 inputs in the fair value measurement hierarchy. We also have short-term financial instruments, primarily cash equivalents, accounts receivable, and accounts payable, for which the carrying value approximated fair value at March 31, 2021 and December 31, 2020. 

13.  Subsequent Events

On April 30, 2021, we completed the sale of our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312 million with an effective date of March 1, 2021. The sale included approximately 78,700 net acres, which are located in the southernmost portion of the Corporation's Bakken position and are not connected to Hess Midstream LP infrastructure. Net production from the acreage during the first quarter of 2021 was approximately 4,500 barrels of oil equivalent per day (boepd).

On April 13, 2021, we amended the Corporation's fully undrawn $3.5 billion revolving credit facility by extending the facility's expiration date for one year to May 2024 and incorporating customary provisions for the eventual replacement of the London Interbank Offered Rate (LIBOR).

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PART I - FINANCIAL INFORMATION (CONT'D.)

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 March 31, 2021 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, 2020.  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 discussed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2020.

Overview

Hess Corporation is a global E&P company engaged in exploration, development, production, transportation, purchase and sale of crude oil, natural gas liquids, and natural gas with production operations located primarily in the United States (U.S.), Guyana, the Malaysia/Thailand Joint Development Area (JDA), Malaysia, and Denmark. We conduct exploration activities primarily offshore Guyana, in the U.S. Gulf of Mexico, and offshore Suriname and Canada. At the Stabroek Block (Hess 30%), offshore Guyana, we have announced eighteen significant discoveries. The Liza Phase 1 development achieved first production in December 2019, and has a nameplate production capacity of approximately 120,000 gross bopd. The Liza Phase 2 development was sanctioned in the second quarter of 2019 and remains on track to achieve first production by early 2022, with production capacity of approximately 220,000 gross bopd. A third development, Payara, was sanctioned in the third quarter of 2020 and is expected to achieve first production in 2024, with production capacity of approximately 220,000 gross bopd. The discovered resources to date on the Stabroek Block are expected to underpin up to ten floating production, storage and offloading vessels (FPSOs) with the first six FPSOs expected by 2027.

Our Midstream operating segment, which is comprised of Hess Corporation’s approximate 46% consolidated ownership interest in Hess Midstream LP at March 31, 2021, provides fee-based services, including gathering, compressing and processing natural gas and fractionating natural gas liquids (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. See Note 4, Hess Midstream LP in the Notes to Consolidated Financial Statements.

Hess Response to Global Pandemic

COVID-19 continues to have a profound impact on society and industry. The Corporation’s first priority in the midst of the pandemic has been the health and safety of the Hess workforce and local communities where the Corporation operates. 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.

First Quarter Outlook

The 2021 E&P capital and exploratory expenditure budget is $1.9 billion, with more than 80% allocated to Guyana and the Bakken. Oil and gas production in 2021, excluding Libya, is now forecast to be in the range of 290,000 boepd to 295,000 boepd. For the remainder of 2021, we have hedged 120,000 bopd with $55 WTI put options and 30,000 bopd with $60 Brent put options.

In March 2021, the Corporation received net proceeds of $70 million for the public offering of 3,450,000 Class A shares of Hess Midstream LP. In March 2021, we entered into an agreement to sell our interests in Denmark for total consideration of $150 million, with an effective date of January 1, 2021. The sale is expected to close during the third quarter of 2021, subject to customary closing conditions. On April 30, 2021, we completed the sale of our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312 million, with an effective date of March 1, 2021.

Net cash provided by operating activities was $591 million in the first quarter of 2021, compared with $445 million in the first quarter of 2020.  Net cash provided by operating activities before changes in operating assets and liabilities was $815 million in the first quarter of 2021 and $502 million in the first quarter of 2020.  Capital expenditures were $303 million in the first quarter of 2021 and $666 million in the first quarter of 2020. Excluding our Midstream segment, we ended the first quarter of 2021 with approximately $1.86 billion in cash and cash equivalents. In 2021, based on current forward strip crude oil prices, we expect cash flow from operating activities, expected proceeds from asset sales, and cash and cash equivalents at March 31, 2021 will be sufficient to fund our capital investment program and dividends. We may take any of the following steps, or a combination thereof, to improve our liquidity and financial position: reduce the planned capital program and other cash outlays, including dividends, pursue asset sales, borrow against our committed revolving credit facility, or issue debt or equity securities.

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PART I - FINANCIAL INFORMATION (CONT'D.)

Overview (continued)

First Quarter Results

Net income was $252 million in the first quarter of 2021, compared with a net loss of $2,433 million in the first quarter of 2020.  Excluding items affecting comparability of earnings between periods detailed on page 24, we incurred an adjusted net loss of $182 million in the first quarter of 2020.  The improvement in first quarter 2021 results against adjusted results for the prior-year quarter is primarily due to higher realized selling prices, contribution from the sale of two VLCC cargos, and lower depletion, depreciation and amortization expenses.

Exploration and Production Results

In the first quarter of 2021, E&P had net income of $308 million, compared with a net loss of $2,371 million in the first quarter of 2020.  Excluding items affecting comparability of earnings between periods, the adjusted net loss was $120 million in the first quarter of 2020.  Total net production, excluding Libya, averaged 315,000 boepd in the first quarter 2021, compared with 344,000 boepd in the first quarter of 2020 or 332,000 boepd pro forma for the sale of our interest in the Shenzi Field.  The average realized crude oil selling price, including hedging, was $50.02 per barrel in the first quarter of 2021, compared with $45.94 per barrel in the first quarter of 2020.  The average realized NGL selling price in the first quarter of 2021 was $29.49 per barrel, compared with $9.32 per barrel in the prior-year quarter, while the average realized natural gas selling price was $4.90 per thousand cubic feet (mcf) in the first quarter of 2021, compared with $3.16 per mcf in the first quarter of 2020.

The following is an update of significant E&P activities:

•In North Dakota, net production from the Bakken oil shale play averaged 158,000 boepd for the first quarter of 2021 (2020 Q1: 190,000 boepd), primarily due to reduced drilling activity, lower NGL and natural gas volumes received under percentage of proceeds contracts due to higher NGL prices, and the impact of adverse winter weather. NGL and natural gas volumes received under percentage of proceeds (POP) contracts were 19,000 boepd in the first quarter of 2020, but were reduced to 11,000 boepd in the first quarter of 2021 due to higher realized NGL prices lowering volumes received as consideration for gas processing fees under the POP contracts. During the quarter, we drilled 11 wells, completed 10 wells, and brought 4 new wells online. In February, we increased the number of operated rigs from one to two. We forecast net production to average approximately 155,000 boepd for the second quarter of 2021 and in the range of 155,000 boepd to 160,000 boepd for the full year 2021 reflecting the impact of lower NGL volumes received as consideration for gas processing fees under POP contracts due to higher NGL prices, the sale of the Corporation’s nonstrategic acreage interests, and adverse winter weather.

During the first quarter of 2021, we completed the sale of 4.2 million barrels of Bakken crude oil transported and stored on two VLCCs during 2020, which contributed net income of approximately $70 million in the first quarter of 2021.

On April 30, 2021, we completed the sale of our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312 million with an effective date of March 1, 2021. The sale included approximately 78,700 net acres, which are located in the southernmost portion of the Corporation's Bakken position and are not connected to Hess Midstream LP infrastructure. Net production from the acreage during the first quarter of 2021 was approximately 4,500 boepd.

•In the Gulf of Mexico, net production for the first quarter of 2021 averaged 56,000 boepd (2020 Q1: 74,000 boepd), reflecting the sale of our interest in the Shenzi Field in the fourth quarter of 2020 and natural field decline. Net production from the Shenzi Field was 12,000 boepd in the first quarter of 2020.

•At the Stabroek Block (Hess 30%), offshore Guyana, net production from the Liza Phase 1 development averaged 31,000 bopd for the first quarter of 2021 (2020 Q1: 15,000 bopd). The Liza Destiny FPSO reached its nameplate capacity of 120,000 gross bopd in December 2020 and remained at this level during the first quarter of 2021. In mid-April, production from the Liza Destiny FPSO was curtailed for several days after a leak was detected in the flash gas compressor discharge silencer. Production has since ramped back up and is expected to remain in the range of 100,000 to 110,000 gross bopd until repairs to the discharge silencer are completed in approximately three months. Following this repair, production is expected to return to, or above, nameplate capacity. In addition, an order has been placed for an upgraded flash gas compression system, which is expected to be installed on the Liza Destiny in the fourth quarter of 2021.

Startup of 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 track for early 2022. The third development, Payara, will utilize the Prosperity FPSO with an expected capacity of 220,000 gross bopd. First oil is expected in 2024. A fourth development, Yellowtail, has been identified on the Stabroek Block. The operator, Esso Exploration and Production Guyana Limited, expects to submit a plan of development to the government of Guyana in the second half of this year. Pending government approval and project sanctioning, the Yellowtail project is expected to achieve first oil in 2025. The discovered resources to date on the Stabroek Block are expected to underpin up to ten FPSOs with the first six FPSOs expected by 2027.

17

PART I - FINANCIAL INFORMATION (CONT'D.)

Overview (continued)

In April 2021, we announced a discovery at the Uaru-2 well, which encountered approximately 120 feet of high quality oil bearing sandstone reservoir, including newly identified intervals below the original Uaru-1 discovery. The well was drilled in 5,659 feet of water and is located approximately 6.8 miles south of the Uaru-1 well.

The Stena DrillMax is currently appraising the Longtail discovery, which will include a planned sidetrack. The Noble Don Taylor will drill the Mako-2 well after Uaru-2, and the Stena Carron is currently drilling the Koebi-1 exploration well. The Noble Tom Madden, the Noble Bob Douglas and the Noble Sam Croft, which recently arrived at the Stabroek Block, are primarily focused on development drilling.

•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged 37,000 boepd for the first quarter of 2021 (2020 Q1: 32,000 boepd), including contribution from unitized acreage in Malaysia, while net production from North Malay Basin, offshore Peninsular Malaysia, averaged 27,000 boepd for the first quarter of 2021 (2020 Q1: 26,000 boepd). Net production was higher at the JDA and North Malay Basin due to a recovery in economic activity.

•At the Waha fields (Hess 8%), onshore Libya, net production averaged approximately 18,000 boepd (2020 Q1: 5,000 boepd), with the increase from the prior-year quarter due to the lifting of force majeure by the national oil company of Libya in October 2020.

•In March, we entered into an agreement to sell our interests in Denmark for total consideration of $150 million, with an effective date of January 1, 2021. Net production from Denmark during the first quarter of 2021 was 6,000 boepd (2020 Q1: 7,000 boepd). The sale is expected to close during the third quarter of 2021, subject to customary adjustments.

The following is an update of significant Midstream activities during the first quarter of 2021:

•In March 2021, the Corporation received net proceeds of $70 million from the public offering of 3,450,000 Hess-owned Class A shares of Hess Midstream LP. After giving effect to this transaction, the Corporation owns an approximate 46% interest in Hess Midstream LP, on a consolidated basis.

Consolidated Results of Operations

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

	Three Months Ended March 31,
	2021		2020
	(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation:
Exploration and Production	$	308	$	(2,371)
Midstream	75		61
Corporate, Interest and Other	(131)		(123)
Total	$	252	$	(2,433)
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$	0.82	$	(8.00)
Diluted	$	0.82	$	(8.00)

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 March 31,
	2021		2020
	(In millions)
Items Affecting Comparability of Earnings Between Periods, After-Tax:
Exploration and Production	$	—	$	(2,251)
Midstream	—		—
Corporate, Interest and Other	—		—
Total	$	—	$	(2,251)

The items in the table above are explained on page 24.

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 March 31,
	2021		2020
	(In millions)
Adjusted Net Income (Loss) Attributable to Hess Corporation:
Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)
Less: Total items affecting comparability of earnings between periods, after-tax	—		(2,251)
Adjusted Net Income (Loss) Attributable to Hess Corporation	$	252	$	(182)

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:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Net cash provided by operating activities before changes in operating assets and liabilities:
Net cash provided by (used in) operating activities	$	591	$	445
Changes in operating assets and liabilities	224		57
Net cash provided by (used in) operating activities before changes in operating assets and liabilities	$	815	$	502

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 page 24.  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 March 31,
	2021		2020
	(In millions)
Revenues and Non-Operating Income
Sales and other operating revenues	$	1,898	$	1,354
Other, net	16		8
Total revenues and non-operating income	1,914		1,362
Costs and Expenses
Marketing, including purchased oil and gas	542		425
Operating costs and expenses	208		214
Production and severance taxes	37		42
Midstream tariffs	262		241
Exploration expenses, including dry holes and lease impairment	33		189
General and administrative expenses	49		52
Depreciation, depletion and amortization	355		521
Impairment	—		2,126
Total costs and expenses	1,486		3,810
Results of Operations Before Income Taxes	428		(2,448)
Provision (benefit) for income taxes	120		(77)
Net Income (Loss) Attributable to Hess Corporation	$	308	$	(2,371)

Excluding the E&P items affecting comparability of earnings between periods detailed on page 24, 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:  Higher realized selling prices in the first quarter of 2021, increased after-tax results by approximately $270 million, compared to the same period in 2020.  Average selling prices were as follows:

	Three Months Ended March 31,
	2021		2020
Average Selling Prices (a)
Crude Oil – Per Barrel (Including Hedging)
United States
North Dakota (b)	$	44.97	$	44.05
Offshore	53.03		49.33
Total United States	46.73		45.63
Guyana	60.37		43.26
Malaysia and JDA	63.27		51.24
Other (c)	57.66		55.60
Worldwide	50.02		45.94
Crude Oil – Per Barrel (Excluding Hedging)
United States
North Dakota (b)	$	47.62	$	40.54
Offshore	56.53		45.65
Total United States	49.56		42.07
Guyana	61.85		36.79
Malaysia and JDA	63.27		51.24
Other (c)	59.61		49.14
Worldwide	52.52		42.08
Natural Gas Liquids – Per Barrel
United States
North Dakota	$	30.32	$	9.31
Offshore	21.25		9.39
Worldwide	29.49		9.32
Natural Gas – Per Mcf
United States
North Dakota	$	5.93	$	1.28
Offshore	2.95		1.32
Total United States	4.78		1.30
Malaysia and JDA	5.04		4.71
Other (c)	2.69		4.26
Worldwide	4.90		3.16

(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 first quarter of 2021 would be $56.54 (2020 Q1: $49.44) per barrel for crude oil (including hedging), $59.04 (2020 Q1: $45.58) per barrel for crude oil (excluding hedging), $29.73 (2020 Q1: $9.52) per barrel for NGLs and $5.02 (2020 Q1: $3.26) per mcf for natural gas.

(b)Excluding the two VLCC cargo sales totaling 4.2 million barrels, the first quarter 2021 North Dakota crude oil price excluding hedging was $53.30 per barrel and $49.73 per barrel including hedging.

(c)Other includes our interests in Denmark and Libya.

Crude oil hedging activities were a net loss of $51 million before and after income taxes in the first quarter of 2021, and a net gain of $64 million before and after income taxes in the first quarter of 2020.

As of March 31, 2021, we have WTI put options with an average monthly floor price of $55 per barrel for 120,000 bopd, and Brent put options with an average monthly floor price of $60 per barrel for 30,000 bopd for the remainder of the year.  We expect noncash put option premium amortization, which will be reflected in realized selling prices, to reduce our second quarter results by $64 million and our full year 2021 results by approximately $245 million.

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 March 31,
	2021		2020
	(In thousands)
Crude Oil – Barrels
United States
North Dakota	84		114
Offshore	36		48
Total United States	120		162
Guyana	31		15
Malaysia and JDA	4		4
Other (a)	22		10
Total	177		191
Natural Gas Liquids – Barrels
United States
North Dakota	49		49
Offshore	4		7
Total United States	53		56
Natural Gas – Mcf
United States
North Dakota	151		162
Offshore	95		113
Total United States	246		275
Malaysia and JDA	360		325
Other (a)	11		11
Total	617		611
Barrels of Oil Equivalent (b)	333		349
Crude oil and natural gas liquids as a share of total production	69	%	71	%

(a)Other includes our interest in Denmark and Libya. Net production from Libya was 18,000 boepd in the first quarter of 2021 compared with 5,000 boepd in the first quarter of 2020. Net production form Denmark was 6,000 boepd in the first quarter of 2021, compared with 7,000 boepd in the first quarter of 2020.

(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 290,000 boepd and 295,000 boepd for the second quarter and for the full year 2021.

United States:  North Dakota net production was lower in the first quarter of 2021, compared to the corresponding period in 2020, primarily due to reduced drilling activity, lower NGL and natural gas volumes received under percentage of proceeds contracts due to higher NGL prices, and the impact of adverse winter weather. Total offshore net production was lower in the first quarter of 2021, compared to the corresponding period in 2020, primarily due to the sale of our working interest in the Shenzi Field in the deepwater Gulf of Mexico in the fourth quarter of 2020 and natural field decline. Net production from the Shenzi Field was 12,000 boepd in the first quarter of 2020.

International:  Net oil production in Guyana was higher in the first quarter of 2021, compared to the corresponding period in 2020, due to the production ramp up from the Liza Phase 1 development. Net oil production in Libya was higher in the first quarter of 2021 due to the lifting of force majeure in October 2020 and net natural gas production was higher at Malaysia and JDA reflecting higher natural gas nominations due to a recovery in economic activity.

22

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Sales Volumes:  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 March 31,
	2021	2020
	(In thousands)
Crude oil – barrels (a)	20,395	16,052
Natural gas liquids – barrels	4,802	5,097
Natural gas – mcf	55,513	55,620
Barrels of Oil Equivalent (b)	34,449	30,419
Crude oil – barrels per day	227	176
Natural gas liquids – barrels per day	53	56
Natural gas – mcf per day	617	611
Barrels of Oil Equivalent Per Day (b)	383	334

(a)Sales volumes for the first quarter of 2021 include 4.2 million barrels that were stored on VLCCs at December 31, 2020.

(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 higher in the first quarter of 2021, compared with the corresponding period in 2020, primarily due to higher benchmark crude oil prices on purchased volumes and the inclusion of $173 million for the cost of the 4.2 million barrels of crude oil on VLCCs sold in the quarter.

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 approximately five percent in the first quarter of 2021, compared with the first quarter of 2020, but were slightly higher on a per-unit basis in the first quarter of 2021, compared with the corresponding period in 2020, primarily due to the impact of lower production volumes.

Midstream Tariffs Expense:  Tariffs expense increased in the first quarter of 2021, compared with the corresponding period in 2020, primarily due to higher minimum volume commitments and tariff rates.  We estimate Midstream tariffs expense to be in the range of $260 million and $270 million in the second quarter of 2021 and in the range of $1,090 million and $1,115 million for the full year 2021.

Depreciation, Depletion and Amortization (DD&A):  DD&A expense and per unit rates were lower in the first quarter of 2021, compared with the prior-year period due to the impact of first quarter 2020 impairment charges and year-end 2020 revisions and additions to proved reserves. Lower first quarter 2021 production volumes also contributed to the decline in DD&A expense compared to the first quarter of 2020.

Unit Costs:  Unit cost per 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 March 31,				Three Months Ended June 30,	Twelve Months Ended December 31,
	2021		2020		2021	2021
Cash operating costs (b)	$	9.81	$	9.70	$12.00 — $13.00	$11.00 — $12.00
DD&A (c)	11.83		16.44		11.50 — 12.50	12.00 — 13.00
Total Production Unit Costs	$	21.64	$	26.14	$23.50 — $25.50	$23.00 — $25.00

(a)Forecast information excludes any contribution from Libya.

(b)Cash operating costs per boe, excluding Libya, were $10.21 in the first quarter of 2021, compared with $9.61 in the first quarter of 2020.

(c)DD&A per boe, excluding Libya, was $12.36 in the first quarter of 2021, compared with $16.64 in the first quarter of 2020.

23

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Exploration Expenses:  Exploration expenses were as follows:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Exploratory dry hole costs (a)	$	—	$	135
Exploration lease and other impairment (b)	4		32
Geological and geophysical expense and exploration overhead	29		22
Total Exploration Expense	$	33	$	189

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

(b)First quarter 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 $40 million to $45 million in the second quarter of 2021 and in the range of $170 million to $180 million for the full year 2021.

Income Taxes:  The increase in income tax expense in the first quarter of 2021, compared to the corresponding period in 2020, is primarily due to higher pre-tax income in Guyana and Libya.  Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense in the first quarter of 2021 was $40 million, compared with $9 million in the first quarter of 2020.  Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense is expected in the range of $25 million to $30 million for the second quarter of 2021 and $105 million to $115 million for the full year 2021.

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 March 31,
	Pre-Tax				After-Tax
	2021		2020		2021		2020
	(In millions)
Impairment	$	—	$	(2,126)	$	—	$	(2,049)
Dry hole, lease impairment and other exploration expenses	—		(152)		—		(150)
Crude oil inventories write-down	—		(53)		—		(52)
	$	—	$	(2,331)	$	—	$	(2,251)

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 and to impair certain exploration leasehold costs.

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.

24

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Midstream

Following is a summarized income statement for our Midstream operations:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Revenues and Non-Operating Income
Sales and other operating revenues	$	289	$	291
Other, net	3		2
Total revenues and non-operating income	292		293
Costs and Expenses
Operating costs and expenses	60		92
General and administrative expenses	7		8
Interest expense	23		25
Depreciation, depletion and amortization	40		38
Total costs and expenses	130		163
Results of Operations Before Income Taxes	162		130
Provision (benefit) for income taxes	3		2
Net Income (Loss)	159		128
Less: Net income (loss) attributable to noncontrolling interests	84		67
Net Income (Loss) Attributable to Hess Corporation	$	75	$	61

Sales and other operating revenues were lower in the first quarter of 2021, compared to the corresponding period in 2020, primarily due to lower pass-through rail transportation revenue partially offset by higher minimum volume commitments and tariff rates.  Operating costs and expenses for the first quarter of 2021 decreased, compared to the corresponding period in 2020, primarily due to lower pass-through transportation costs.

Excluding items affecting comparability of earnings, net income attributable to Hess Corporation from the Midstream segment is estimated to be in the range of $60 million to $70 million in the second quarter of 2021 and in the range of $280 million and $290 million for the full year 2021.

Corporate, Interest and Other

The following table summarizes Corporate, Interest and Other expenses:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Corporate and other expenses	$	37	$	39
Interest expense	94		88
Corporate, Interest and Other expenses before income taxes	131		127
Provision (benefit) for income taxes	—		(4)
Total Corporate, Interest and Other Expenses After Income Taxes	$	131	$	123

Corporate and other expenses in the first quarter of 2021, were comparable to the corresponding period in 2020.  Interest expense, net was higher in the first quarter of 2021, compared to the corresponding period in 2020, due to interest incurred on the $1.0 billion three year term loan entered into in March 2020.

Second quarter 2021 corporate expenses are expected to be in the range of $30 million to $35 million, and interest expense is expected to be in the range of $95 million to $100 million. We estimate corporate expenses for full year 2021 to be in the range of $130 million to $140 million, and interest expense to be in the range of $380 million to $390 million.

25

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

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 Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2020.

Liquidity and Capital Resources

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

	March 31, 2021			December 31, 2020
	(In millions, except ratio)
Cash and cash equivalents (a)	$	1,866		$	1,739
Current maturities of long-term debt	13			10
Total debt (b)	8,286			8,296
Total equity	6,643			6,335
Debt to capitalization ratio (c)	46.6		%	47.5		%

(a)Includes $4 million of cash attributable to our Midstream segment at March 31, 2021 (December 31, 2020: $4 million) of which, $2 million is held by Hess Midstream LP at March 31, 2021 (December 31, 2020: $3 million).

(b)At March 31, 2021, includes $1,899 million of debt outstanding from our Midstream segment (December 31, 2020: $1,910 million) that is non-recourse to Hess Corporation.

(c)Total Consolidated Debt of Hess Corporation (including finance leases and excluding Midstream non-recourse debt) as a percentage of Total Capitalization of Hess Corporation as defined under Hess Corporation's term loan and revolving credit facility financial covenants. Total Capitalization excludes the impact of noncash impairment charges and non-controlling interests.

Cash Flows

The following table summarizes our cash flows:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Net cash provided by (used in):
Operating activities	$	591	$	445
Investing activities	(385)		(818)
Financing activities	(79)		908
Net Increase (Decrease) in Cash and Cash Equivalents	$	127	$	535

Operating activities:  Net cash provided by operating activities was $591 million in the first quarter of 2021, compared to $445 million in the first quarter of 2020.  The increase in 2021 operating cash flows primarily reflects higher realized selling prices and the sale of 4.2 million barrels of Bakken crude oil loaded on two VLCCs in the first quarter of 2021. Changes in operating assets and liabilities was a use of cash of $224 million in the first quarter of 2021, and a use of cash of $57 million in the first quarter of 2020. Changes in operating assets and liabilities in 2021 were primarily due to an increase in accounts receivable and a reduction in accounts payable.

Investing activities:  Additions to property, plant and equipment of $385 million in the first quarter of 2021 were down $433 million compared with the corresponding period in 2020.  The decrease primarily reflects reduced drilling activity.

26

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

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

	Three Months Ended March 31,
	2021		2020
	(In millions)
Additions to property, plant and equipment - E&P:
Capital expenditures incurred - E&P	$	(280)	$	(609)
Increase (decrease) in related liabilities	(78)		(131)
Additions to property, plant and equipment - E&P	$	(358)	$	(740)
Additions to property, plant and equipment - Midstream:
Capital expenditures incurred - Midstream	$	(23)	$	(57)
Increase (decrease) in related liabilities	(4)		(21)
Additions to property, plant and equipment - Midstream	$	(27)	$	(78)

Financing activities: Hess Midstream repaid a net total of $10 million from its revolving credit facilities in the first quarter of 2021 and borrowed a net total of $60 million in the first quarter of 2020.  Borrowings in the first quarter of 2020 also included our $1.0 billion three year term loan. We paid common stock dividends totaling $80 million in the first quarter of 2021, compared to $81 million in the first quarter of 2020.  In addition, net cash outflows to noncontrolling interests were $67 million in the first quarter of 2021 and $63 million in the first quarter of 2020. In the first quarter of 2021, we received net proceeds of $70 million from the public offering of 3,450,000 Hess-owned Class A shares in Hess Midstream LP.

Future Capital Requirements and Resources

At March 31, 2021, we had $1.86 billion in cash and cash equivalents, excluding Midstream, and total liquidity of approximately $5.5 billion.  On April 13, 2021, we amended the Corporation's fully undrawn $3.5 billion revolving credit facility by extending the facility's expiration date for one year to May 2024. Oil and gas production in 2021, excluding Libya, is forecast to be in the range of 290,000 boepd to 295,000 boepd. For the remainder of 2021, we have hedged 120,000 bopd with $55 WTI put options and 30,000 bopd with $60 Brent put options.

On April 30, 2021, we completed the sale of our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312 million, with an effective date of March 1, 2021, and expect to receive proceeds in the third quarter of 2021 from the sale of our interests in Denmark for total consideration of $150 million, with an effective date of January 1, 2021.

Net cash provided by operating activities was $591 million in the first quarter of 2021, compared with $445 million in the first quarter of 2020.  Net cash provided by operating activities before changes in operating assets and liabilities was $815 million in the first quarter of 2021 and $502 million in the first quarter of 2020.  Capital expenditures were $303 million in the first quarter of 2021 and $666 million in the first quarter of 2020.   In 2021, based on current forward strip crude oil prices, we expect cash flow from operating activities, expected proceeds from asset sales, and cash and cash equivalents at March 31, 2021 will be sufficient to fund our capital investment program and dividends. We may take any of the following steps, or a combination thereof, to improve our liquidity and financial position: reduce the planned capital program and other cash outlays, including dividends, pursue asset sales, borrow against our committed revolving credit facility, or issue debt or equity securities.

27

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

The table below summarizes the capacity, usage, and available capacity for borrowings and letters of credit under committed and uncommitted credit facilities at March 31, 2021:

	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)	229		—		229		229		—
Total - Hess Corporation		$	3,904	$	—	$	283	$	283	$	3,621
Midstream
Revolving credit facility (b)	December, 2024	$	1,000	$	174	$	—	$	174	$	826
Total - Midstream		$	1,000	$	174	$	—	$	174	$	826

(a)Committed and uncommitted lines have expiration dates through 2021.

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

Hess Corporation:

On April 13, 2021, we amended the Corporation's fully undrawn $3.5 billion revolving credit facility that had an expiration date in May 2023, by extending the facility for one year to May 2024 and incorporating customary provisions for the eventual replacement of LIBOR, among other changes as set forth in the amended credit agreement. This facility can be used for borrowings and letters of credit. Borrowings on the facility will generally bear interest at 1.40% above LIBOR, though the interest rate is subject to adjustment if the Corporation’s credit rating changes. At March 31, 2021, Hess Corporation had no outstanding borrowings or letters of credit under its revolving credit facility.

In March 2020, we entered into a $1 billion three year term loan agreement with a maturity date of March 16, 2023. Borrowings under the term loan generally bear interest at LIBOR plus an applicable margin of 2.25% until the term loan's first anniversary. The applicable margin varies based on the credit rating of the Corporation’s senior unsecured long-term debt and will increase by 0.25% on each anniversary of the term loan.

The revolving credit facility, including as amended, and term loan are subject to customary representations, warranties, customary events of default and covenants, including a financial covenant limiting the ratio of Total Consolidated Debt to Total Capitalization of the Corporation and its consolidated subsidiaries to 65%, and a financial covenant limiting the ratio of secured debt to Consolidated Net Tangible Assets of the Corporation and its consolidated subsidiaries to 15% (as these capitalized terms are defined in the credit agreement for the revolving credit facility and the term loan agreement). The indentures for the Corporation's fixed-rate public notes limit the ratio of secured debt to Consolidated Net Tangible Assets (as that term is defined in the indentures) to 15%. At March 31, 2021, Hess Corporation was in compliance with these financial covenants.

Two of the three major credit rating agencies that rate our debt have assigned an investment grade rating. In March 2021, Standard and Poor’s Ratings Services affirmed our credit rating at BBB- and revised the outlook to stable (from negative). Fitch Ratings affirmed a BBB- credit rating and stable outlook in August 2020 and Moody’s Investors Service affirmed our credit rating at Ba1 with stable outlook, which is below investment grade, in March 2020.

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

Midstream:

At March 31, 2021, 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 five 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 five 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

28

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

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 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 March 31, 2021.  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 March 31, 2021, borrowings of $174 million were drawn under HESM Opco’s revolving credit facility, and borrowings of $398 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 $121 million at March 31, 2021 that are used to reduce our exposure to fluctuating foreign exchange rates for various currencies.  A 10% strengthening or weakening in the U.S. Dollar exchange rate is estimated to be a loss or gain of less than $5 million, respectively, at March 31, 2021.

At March 31, 2021, our total long-term debt, which was substantially comprised of fixed-rate instruments, had a carrying value of $8,286 million and a fair value of $9,381 million.  A 15% increase or decrease in interest rates would decrease or increase the fair value of debt by approximately $405 million or $420 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 March 31, 2021, we have outstanding WTI and Brent crude oil put option contracts.  As of March 31, 2021, an assumed 10% increase in the forward WTI and Brent crude oil prices would reduce the fair value of these derivative instruments by approximately $50 million, while an assumed 10% decrease in the same crude oil prices would increase the fair value of these derivative instruments by approximately $110 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, NGL 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 proposed asset sale; 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, NGL and natural gas and competition in the oil and gas exploration and production industry, including as a result of COVID-19;

•reduced demand for our products, including due to COVID-19 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;

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

•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 flaring as well as fracking bans;

•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;

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

•the ability to satisfy the closing conditions of the proposed asset sale;

•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, including 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 Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2020 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 March 31, 2021, John B. Hess, Chief Executive Officer, and John P. Rielly, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of March 31, 2021.

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 March 31, 2021 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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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.

32

PART II – OTHER INFORMATION (CONT'D)

Item 6.   Exhibits. 

Exhibits
4(1)	Extension and Amendment Agreement, dated as of April 13, 2021, among Hess Corporation, the subsidiary party thereto, the lenders party thereto, and JPMorgan Chase Bank, N.A., as administrative agent incorporated by reference to Exhibit 10(1) of Form 8-K of the Registrant, filed on April 13, 2021.
10(1)*	Form of Performance Award Agreement for three-year period ending December 31, 2023 under the 2017 Long-Term Incentive Plan.
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 March 31, 2021, has been formatted in Inline XBRL.

* The exhibit relates to executive compensation plans and arrangements.

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: May 6, 2021

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EX-10.1

Exhibit 10(1)

HESS CORPORATION 2017 LONG-TERM INCENTIVE PLAN

Performance Award Agreement

Participant:	FIRST NAME - LAST NAME
Grant Date:	DATE
Number of Performance Shares	# OF PERFORMANCE SHARE UNITS

* * * * *

This PERFORMANCE AWARD AGREEMENT (this “Agreement”), dated as of the Grant Date specified above, is entered into by and between HESS CORPORATION, a Delaware corporation (the “Corporation”), and the Participant specified above, pursuant to the Shareholder Value Program under the Hess Corporation 2017 Long-Term Incentive Plan, as in effect and as amended from time to time (the “Plan”).

WHEREAS, it has been determined under the Plan that it would be in the best interests of the Corporation to grant the Performance Award provided for herein to the Participant as an inducement to remain in the employment of the Corporation (and/or any Subsidiary), and as an incentive for improved performance toward corporate goals during such employment;

WHEREAS, pursuant to the provisions of the Plan, the Committee has authorized the grant to the Participant of a Performance Award in accordance with the terms and conditions of this Agreement; and

WHEREAS, the Participant and the Corporation desire to enter into this Agreement to evidence and confirm the grant of such Performance Award on the terms and conditions set forth herein.

NOW, THEREFORE, in consideration of the mutual covenants and premises hereinafter set forth and for other good and valuable consideration, the parties hereto hereby mutually covenant and agree as follows.

1.    Incorporation By Reference; Document Receipt. This Agreement is subject in all respects to the terms and provisions of the Plan (including, without limitation, any amendments thereto adopted at any time and from time to time unless such amendments are expressly not intended to apply to the grant of the Performance Award hereunder), all of which terms and provisions are made a part of and incorporated in this Agreement as if each were expressly set forth mutatismutandis herein. Any capitalized term not defined in this Agreement shall have the same meaning as is ascribed thereto under the Plan. The Participant hereby acknowledges receipt of a prospectus describing the Plan and the Awards thereunder and that he has read it carefully and fully understands its content. In the event of any conflict between the terms of this Agreement and the terms of the Plan, the terms of the Plan shall control.

2.    Grant of Performance Award. Pursuant to the provisions of the Plan, the Corporation as of the date set forth above (the “Grant Date”) has granted to the Participant, and hereby evidences the grant to the Participant of, subject to the terms and conditions set forth herein and in the Plan, a Performance Award consisting of the number of Performance Shares specified above. A Performance Share is an unfunded and unsecured obligation to deliver up to two Shares (or a portion thereof) or the cash equivalent thereof (determined in accordance with Section 3), subject to the terms and conditions of this Agreement and those of the Plan. References herein to Performance Shares are to the Performance Shares comprising such Performance Award granted pursuant to this Agreement.

3.    Payment of Earned Performance Shares. Subject to the provisions of Section 5 and Section 6, after the end of the Performance Cycle described in Section 4(a), the Committee shall certify in writing on the date (the “vesting date”) of its first regular meeting following the end of the Performance Cycle whether, and to what extent, the performance goal set forth in Section 4(b) has been achieved and determine and certify in writing the number of Performance Shares earned pursuant to Section 4. The number of such Performance Shares so earned shall be paid by the Corporation as soon as administratively practicable after the vesting date; provided that in no event shall such payment be made later than March 15 of the calendar year that immediately follows the last day of the Performance Cycle. To the extent that the Performance Shares are not earned pursuant to Section 4, such Performance Shares shall be forfeited. Payments hereunder shall be made in Shares, unless the Committee, in its sole discretion, affirmatively determines that such payments shall be made in cash, or a combination of Shares and cash. If a cash payment is made in lieu of delivering Shares, the amount of such payment shall be equal to the Fair Market Value of such Shares as of the trading date immediately prior to the date of such payment, less applicable tax withholdings in accordance with Section 12.03 of the Plan.

4.    Vesting Criteria Applicable to Performance Shares.

(a)    Performance Cycle. The Performance Cycle for the Performance Award granted pursuant to this Agreement shall commence on January 1, 2021, and shall end on December 31, 2023.

(b)    Performance Goal. The performance goal for the Performance Cycle is the total return per Share to the Corporation’s shareholders, inclusive of dividends paid, during the Performance Cycle in comparison to the total return per share of common stock, inclusive of dividends paid, during the Performance Cycle achieved by the companies that are listed in Exhibit A attached hereto (the “Comparison Companies”) as well as the S&P 500 Total Return Index (the “S&P Total Return Index”), in each case as set forth in this Section 4(b). For purposes of this Agreement, such total shareholder return (“Total Shareholder Return”) for the Corporation and each of the Comparison Companies shall be measured by dividing (A) the sum of (1) the dividends paid (regardless of whether paid in cash or property) on the common stock of such company during the Performance Cycle, assuming reinvestment of such dividends in such stock (based on the closing price of such stock on the date such dividend is paid), plus (2) the average closing price of a share of such stock on the

2

principal United States exchange on which the stock trades for the 60 trading days immediately prior to and including the last day of the Performance Cycle (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events)(the “Ending Average Value”) minus the average closing price of a share of such company’s common stock on the principal United States exchange on which the stock trades for the 60 trading days occurring immediately prior to the first day of the Performance Cycle (the “Beginning Average Value”), by (B) the Beginning Average Value. For the avoidance of doubt, it is intended that the foregoing calculation of Total Shareholder Return for the Corporation and each of the Comparison Companies shall take into account not only the reinvestment of dividends in a share of common stock of the Corporation and any Comparison Company but also capital appreciation or depreciation in the shares deemed acquired by such reinvestment. For purposes of this Agreement, Total Shareholder Return for the S&P 500 Total Return Index shall be measured by dividing (A) the average closing price of a share of such index on the principal United States exchange on which the index trades for the 60 trading days immediately prior to and including the last day of the Performance Cycle, minus the average closing price of a share of such index on the principal United States exchange on which the index trades to the 60 trading days occurring immediately prior to the first day of the Performance Cycle (the “S&P Beginning Average Value”) by (B) the S&P Beginning Average Value. The S&P 500 Total Return Index includes both the capital gains of its underlying securities but also assumes that all distributions, such as dividends are reinvested back into the index. All determinations under this Section 4 shall be made by the Committee.

(c)    Percentage of Performance Shares Earned. Except as provided in Section 6, the Performance Shares shall be earned based on where the Corporation’s Total Shareholder Return during the Performance Cycle ranks in comparison to the Total Shareholder Returns of the Comparison Companies and the S&P Total Return Index during the Performance Cycle. As soon as practicable after the completion of the Performance Cycle, the Total Shareholder Returns of the Corporation, each of the Comparison Companies and the S&P Total Return Index shall be calculated and ranked from first to last (the “TSR Ranking”). The extent to which Performance Shares shall become earned on the vesting date described in Section 3 shall be based on the TSR Ranking attained by the Corporation. The percentage of Performance Shares earned (the “Percentage of Performance SharesEarned”) shall be the percentage set forth in the Percentage of Performance Shares Earned column of the schedule set forth in Exhibit B attached hereto that corresponds to the TSR Ranking attained by the Corporation set forth in the TSR Ranking column of such schedule. The number of Performance Shares earned shall be the product of the number of Performance Shares set forth in Section 2 multiplied by the Percentage of Performance Shares Earned. If at any time during the Performance Cycle, a Comparison Company is acquired, ceases to exist, ceases to be a publicly-traded company, files for bankruptcy, spins off 50% or more of its assets (except as otherwise provided in Exhibit A), or sells all, or substantially all, of its assets, such Comparison Company shall be removed and treated as if it had never been a Comparison Company. The Total Shareholder Returns of the Corporation and the remaining Comparison Companies and the S&P Total Return Index shall be ranked from first to last, and the Percentage of Performance Shares Earned shall be determined as

3

described in this Section 4(c) based on the Corporation’s TSR Ranking among the remaining Comparison Companies and S&P Total Return Index: (i) to the extent the number of Comparison Companies and the S&P Total Return Index plus the Corporation is reduced to 12, 11, 10, 9 or 8, in accordance with the percentage corresponding to Corporation’s TSR Ranking as set forth in Exhibit C-1, C-2, C-3, C-4 or C-5 attached hereto, respectively, and (ii) to the extent that the number of Comparison Companies and the Total Return Index plus the Corporation is reduced to fewer than 8, in accordance with the percentage corresponding to the Corporation’s TSR Ranking as set forth in Exhibit C-5, provided that (1) the Committee may use negative discretion to reduce the Percentage of Performance Shares Earned corresponding to such TSR Ranking of the Corporation such that the Percentage of Performance Shares Earned shall be as reasonably commensurate as possible with the Percentage of Performance Shares Earned that would have resulted if the number of Comparison Companies and the S&P Total Return Index plus the Corporation had been 8, using similar percentile hurdles as exist in Exhibit C-5, with straight-line interpolation between points, and (2) if the Corporation ranks last among the remaining Comparison Companies and the S&P Total Return Index, the Percentage of Performance Shares Earned shall be 0%. Notwithstanding the foregoing provisions of this Section 4(c) to the contrary, if the Corporation’s Total Shareholder Return during the Performance Cycle is negative, the Percentage of Performance Shares Earned shall not exceed 100%.

5.     Termination of Employment. Except as provided in this Section 5, the Participant shall not have any right to any payment hereunder unless the Participant is employed by the Corporation or a Subsidiary on the vesting date pursuant to Section 3.

(a)    Death, Permanent Total Disability or Full Retirement. If (i) the Participant’s employment with the Corporation or any Subsidiary terminates prior to the vesting date pursuant to Section 3 by reason of the Participant’s death, permanent total disability or “Full Retirement” (as defined below), the Participant shall be entitled to receive the same payment, if any (without pro-ration), in respect of the Performance Shares as would have been payable, and at the same time and subject to the same conditions, had the Participant’s employment continued until such vesting date. The existence and date of permanent total disability shall be determined by the Committee and its determination shall be final and conclusive. For purposes of this Agreement, “Full Retirement” shall mean voluntary retirement after attaining at least age 65 with at least five years of continuous service with the Corporation or any Subsidiary prior to the date of such retirement.

(b)    Other than Death, Permanent Total Disability or FullRetirement. If the Participant’s employment with the Corporation or any Subsidiary terminates prior to the vesting date pursuant to Section 3 for any reason other than the Participant’s death, permanent total disability or Full Retirement, all of the Performance Shares and the Participant’s rights with respect thereto shall be immediately forfeited and cancelled without further action by the Corporation or the Participant as of the date of such termination of employment.

(c)    Early Retirement/Termination other than Cause. Notwithstanding Section 5(b), if (i) the Participant’s employment with the Corporation

4

or any Subsidiary terminates prior to the vesting date pursuant to Section 3 by reason of the Participant’s “Early Retirement” (as defined below) or on account of a termination by the Corporation or a Subsidiary other than for Cause, the Participant shall be entitled to receive the same payment, if any, in respect of the Performance Shares as would have been payable, and at the same time and subject to the same conditions, had the Participant’s employment continued until such vesting date, provided that such payment shall be pro-rated based on the number of calendar days of the Performance Cycle elapsed through the date of such Early Retirement or termination other than for Cause. For purposes of this Agreement, “Early Retirement” shall mean voluntary retirement after attaining at least age 55 with at least ten years of continuous service with the Corporation or any Subsidiary prior to the date of such retirement.

(d)    Forfeiture Following Early Retirement or Termination other than Cause. Notwithstanding any other provision of this Agreement to the contrary, if, following termination of the Participant’s employment with the Corporation or any Subsidiary due to Early Retirement or a termination other than for Cause, as described in Section 5(c), the Committee determines in its good faith discretion that the Participant shall have engaged in any Prohibited Activity (as hereinafter defined) at any time during the time through the otherwise applicable vesting date with respect to the Performance Cycle, all of the Performance Shares and the Participant’s rights with respect thereto shall be immediately forfeited and cancelled without further action by the Corporation or the Participant as of the date on which the Participant shall have first entered into such Prohibited Activity. This Section 5(d) shall not constitute the Corporation’s exclusive remedy for the Participant’s engagement in any Prohibited Activity, and the Corporation may seek any additional legal or equitable remedy, including injunctive relief, in any such circumstances. If any provision contained in this Section 5(d) shall be held by any court of competent jurisdiction to be unenforceable, void or invalid, the parties intend that such provision be modified to make it valid and enforceable to the fullest extent permitted by law. If any such provision cannot be modified to be valid and enforceable, such provision shall be severed from this Agreement and the invalidity or unenforceability of such provision shall not affect the validity or enforceability of the remaining provisions. Notwithstanding any other provision of this Section 5(d) to the contrary, upon the occurrence of a Change of Control, the foregoing provisions of this Section 5(d) shall automatically terminate and cease to apply with respect to any Performance Shares that are outstanding and have not previously been forfeited under this Section 5(d). For purposes of this Agreement:

(i)    “Prohibited Activity” shall mean either Competitive Activity or Interference.

(ii)    “Competitive Activity” shall mean that the Participant, directly or indirectly, in any manner or capacity, shall be employed by, serve as a director or manager of, act as a consultant to or maintain any material ownership interest in, any E&P Company or M&R Company that competes with the business of the Corporation or any Subsidiary or affiliate thereof in geographical areas in which the Participant is aware that the Corporation or any Subsidiary or affiliate is engaged, or is considering engaging, unless the Committee agrees to such activity of the Participant in

5

writing; provided, however, that the Participant’s ownership solely as an investor of less than 1% of the outstanding securities of any publicly-traded securities of any E&P Company or M&R Company shall not, by itself, be considered to be Competitive Activity.

(iii)    “Interference” shall mean that the Participant shall, directly or indirectly, interfere with the relationship between the Corporation or any Subsidiary or affiliate of the Corporation and any person (including, without limitation, any business or governmental entity) that to the Participant’s knowledge is, or was, a client, customer, supplier, licensee or partner of the Corporation or any Subsidiary, or had any other business relationship with the Corporation or any Subsidiary.

(iv)     “E&P Company” shall mean any business which is engaged in the business of exploring for, or developing or producing, crude oil or natural gas.

(v)    “M&R Company” shall mean any business which is engaged in the manufacture, generation, purchase, marketing or trading of refined petroleum products, natural gas or electricity.

6.    Change of Control. Notwithstanding anything in Section 3, 4, 5(a) or 5(c) to the contrary, in the event a Change of Control occurs during the Performance Cycle, the Corporation’s Total Shareholder Return, TSR Ranking and the Percentage of Performance Shares Earned shall be determined in accordance with Section 4 for the portion of the Performance Cycle that ends on the date immediately prior to the date of the Change of Control. Provided that the Performance Shares have not been forfeited pursuant to Section 5 prior to the date of the Change of Control, the number of the Performance Shares earned shall be the sum of (a) the product of the number of Performance Shares set forth in Section 2, multiplied by a fraction, the numerator of which is the number of calendar days of the Performance Cycle that elapse through the date immediately prior to the date of the Change of Control and the denominator of which is the full number of calendar days during the Performance Cycle, multiplied by the Percentage of Performance Shares Earned, plus (b) the product of the number of Performance Shares set forth in Section 2, multiplied by a fraction, the numerator of which is the number of calendar days remaining in the Performance Cycle on and following the date of the Change of Control and the denominator of which is the full number of calendar days during the Performance Cycle. The amount payable subject to the terms and conditions hereof in respect of such earned Performance Shares shall be equal to the product of such number of earned Performance Shares multiplied by the Change of Control Price, without interest or other additional earnings (such amount, the “CoC Earned Performance Share Amount”). Except as otherwise provided in this Section 6, the CoC Earned Performance Share Amount shall be paid in a cash lump-sum during, and no later than March 15 of, the calendar year that immediately follows the last day of the Performance Cycle. If, following a Change of Control, the Participant’s employment with the Corporation or any Subsidiary terminates prior to payment of the CoC Earned Performance Share Amount by reason of (w) termination by the Corporation or such Subsidiary without Cause, (x) resignation by the Participant for Good Reason, (y) the Participant’s death or permanent total disability (determined as described in Section 5(a)) or (z) the Participant’s Full Retirement, the Participant shall be

6

entitled to receive payment of the CoC Earned Performance Share Amount in a cash lump-sum not later than 5 business days after the effective date of such termination of employment, provided that if such payment would result in accelerated or additional taxes under Section 409A of the Code then such payment shall be made at the time specified in the immediately preceding sentence as if the Participant’s employment had not so terminated. If, following a Change of Control, the Participant’s employment with the Corporation or any Subsidiary terminates under any circumstances other than those described in the immediately preceding sentence, then the Participant shall not have any right to any payment in respect of the Performance Shares, whether or not earned.

7.    Dividend Equivalents. With respect to the number of Performance Shares set forth in Section 2, the Participant shall be credited with Dividend Equivalents with respect to each such Performance Share equal to the amount per Share of any ordinary cash dividends declared by the Board with record dates during the period beginning on the first day of the Performance Cycle and ending on the earliest to occur of: (a) the last day of the Performance Cycle; (b) the date of a Change of Control and (c) the date such Performance Share terminates or is forfeited under Section 3 or Section 5. The Corporation shall pay in cash to the Participant an amount equal to the product of (i) sum of the aggregate amount of such Dividend Equivalents credited to the Participant, multiplied by (ii) the Percentage of Performance Shares Earned, such amount to be paid as and when the related Performance Shares are paid in accordance with Section 3 or Section 6, as applicable. Any Dividend Equivalents shall be forfeited as and when the related Performance Shares are forfeited in accordance with Section 3, Section 5 or Section 6.

8.    No Rights as a Shareholder. Until shares of Common Stock are issued, if at all, in satisfaction of the Corporation’s obligations under this Agreement, in the time and manner specified in Section 3 or 6, the Participant shall have no rights as a shareholder as to the Shares underlying the Performance Shares.

9.    Beneficiary. The Participant may designate the beneficiary or beneficiaries to receive any payments which may be made in respect of the Performance Shares after the Participant’s death. Any such designation shall be made by the Participant in writing on a beneficiary designation form provided by or on behalf of the Corporation and (unless the Participant has waived such right) may be changed by the Participant from time to time by filing a new beneficiary designation form as provided therein. If the Participant does not designate a beneficiary or if no designated beneficiary survives the Participant, the Participant’s beneficiary shall be the legal representative of his estate.

10.    Tax Withholding. No payment of Shares or cash in respect of the Performance Shares shall be made unless and until the Participant (or his or her beneficiary or legal representative) shall have made arrangements satisfactory to the Committee for the payment of any amounts required to be withheld with respect thereto under all present or future federal, state, local and non-United States tax laws and regulations and other laws and regulations in accordance with Section 12.03 of the Plan. The Corporation shall have the right to deduct from all amounts paid to the Participant in cash in respect of Performance Shares any such amounts. In the case of any payments of

7

Performance Shares in the form of Shares, unless the Participant elects otherwise in advance in writing or is prohibited by law, upon payment of such Shares, such number of such Shares as shall be necessary to pay such amounts shall be sold by the Corporation or its designee on the Participant’s behalf, and the proceeds thereof shall be delivered to the Corporation for remittance to the appropriate governmental authorities. In the event the Committee determines that any amounts are required to be withheld in respect of the Performance Shares prior to payment of such Performance Shares, the Participant shall thereupon pay to the Corporation in cash the full amount so required to be withheld.

11.    Limitations; Governing Law. Nothing herein or in the Plan shall be construed as conferring on the Participant or anyone else the right to continue in the employ of the Corporation or any Subsidiary. The rights and obligations under this Agreement are governed by and construed in accordance with the laws of the State of Delaware, without reference to the principles of conflict of laws thereof.

12.    Non-transferability. Except as otherwise provided by Section 8, the Performance Shares, and any rights and interests with respect thereto, may not be sold, exchanged, transferred, assigned or otherwise disposed of in any way by the Participant (or the Participant’s beneficiary), and may not be pledged or encumbered in any way by the Participant (or the Participant’s beneficiary), and shall not be subject to execution, attachment or similar legal process.

13.    Entire Agreement; Amendment. This Agreement (including the Plan which is incorporated herein by reference) contains the entire agreement between the parties hereto with respect to the subject matter contained herein, and supersedes all prior agreements or prior understandings, whether written or oral, between the parties hereto relating to such subject matter. The Board has the right, in its sole discretion, to amend, alter, suspend, discontinue or terminate the Plan, and the Committee has the right, in its sole discretion, to amend, alter, suspend, discontinue or terminate this Agreement from time to time in accordance with and as provided in the Plan; provided, however, that no such amendment, alteration, suspension, discontinuance or termination of the Plan may materially impair the Participant’s previously accrued rights under this Agreement or the Plan without the Participant’s consent, except as otherwise provided in Section 11 of the Plan. This Agreement may also be modified, amended or terminated by a writing signed by the Participant and the Corporation.

14.    Notices. Any notice which may be required or permitted under this Agreement shall be in writing and shall be delivered in person, or via facsimile transmission, overnight courier service or certified mail, return receipt requested, postage prepaid, properly addressed as follows:

(a)    If the notice is to the Corporation, to the attention of the Secretary of Hess Corporation, 1185 Avenue of the Americas, New York, New York 10036, or at such other address as the Corporation by notice to the Participant may designate in writing from time to time.

(b)    If the notice is to the Participant, at the Participant’s address as shown on the Corporation’s records, or at such other address as the Participant, by notice to the Corporation, may designate in writing from time to time.

8

15.    Compliance with Laws. The issuance of any Shares pursuant to this Agreement shall be subject to, and shall comply with, any applicable requirements of federal and state securities laws, rules and regulations (including, without limitation, the provisions of the Securities Act of 1933, as amended, the Exchange Act and the respective rules and regulations promulgated thereunder), any applicable rules of any exchange on which the Common Stock is listed (including, without limitation, the rules and regulations of the New York Stock Exchange), and any other law, rule or regulation applicable thereto. The Corporation shall not be obligated to issue any of the Common Stock subject to this Agreement if such issuance would violate any such requirements and if issued shall be deemed void ab initio.

16.    Binding Agreement; Further Assurances. This Agreement shall inure to the benefit of, be binding upon, and be enforceable by the Corporation and its successors and assigns. Each party hereto shall do and perform (or shall cause to be done and performed) all such further acts and shall execute and deliver all such other agreements, certificates, instruments and documents as any other party hereto reasonably may request in order to carry out the intent and accomplish the purposes of this Agreement and the Plan and the consummation of the transactions contemplated thereunder.

17.    Counterparts; Headings. This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original, but all of which shall constitute one and the same instrument. The titles and headings of the various sections of this Agreement have been inserted for convenience of reference only and shall not be deemed to be a part of this Agreement.

18.    Severability. The invalidity or unenforceability of any provisions of this Agreement in any jurisdiction shall not affect the validity, legality or enforceability of the remainder of this Agreement in such jurisdiction or the validity, legality or enforceability of any provision of this Agreement in any other jurisdiction, it being intended that all rights and obligations of the parties hereunder shall be enforceable to the fullest extent permitted by law.

19.    Terms of Employment. The Plan is a discretionary plan. The Participant hereby acknowledges that neither the Plan nor this Agreement forms part of the Participant’s terms of employment and nothing in the Plan may be construed as imposing on the Corporation or any Subsidiary a contractual obligation to offer participation in the Plan to any employee of the Corporation or any Subsidiary. Neither the Corporation nor any Subsidiary is under any obligation to grant any further Awards to the Participant under the Plan. If the Participant ceases to be an employee of the Corporation or any Subsidiary for any reason, the Participant shall not be entitled by way of compensation for loss of office or otherwise howsoever to any sum or other benefit to compensate the Participant for the loss of any rights under this Agreement or the Plan. The Participant also acknowledges that the Corporation has adopted a policy prohibiting recipients of equity awarded from the Corporation, including the Performance Shares, from trading in equity derivative instruments to hedge the economic risks of holding Corporation common stock or interests therein. The Participant hereby acknowledges

9

that he will abide by such policy in all respects.

20.    Data Protection. By signing this Agreement, the Participant hereby consents to the holding and processing of personal data provided by the Participant to the Corporation for all purposes necessary for the operation of the Plan. These include, but are not limited to:

(a)    administering and maintaining the Participant’s records;

(b)    providing information to any registrars, brokers or third party administrators of the Plan; and

(c)    providing information to future purchasers of the Corporation or the business in which the Participant works.

21.    Code Section 409A. Payment of the Performance Shares and this Agreement are intended to comply with Section 409A of the Code, and shall be administered and construed in accordance with such intent. Accordingly, the Corporation shall have the authority to take any action, or refrain from taking any action, with respect to this Agreement that it determines is necessary or appropriate to ensure compliance with Code Section 409A (provided that the Corporation shall choose the action that best preserves the value of payments provided to the Participant under this Agreement that is consistent with Code Section 409A). In furtherance, but not in limitation, of the foregoing, notwithstanding any other provisions of this Agreement to the contrary:

(a)    in no event may the Participant designate, directly or indirectly, the calendar year of any payment to be made hereunder;

(b)    if at the time of the Participant’s separation from service, the Corporation determines that the Participant is a “specified employee” within the meaning of Code Section 409A, payments, if any, hereunder that constitute a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service shall be delayed and all such delayed payments shall be paid in full upon the earlier to occur of (i) a date during the thirty-day period commencing six months and one day following such separation from service and (ii) the date of the Participant’s death, provided that such delay shall not apply to any payment that is excepted from coverage by Code Section 409A, such as a payment covered by the short-term deferral exception described in Treasury Regulations Section 1.409A-1(b)(4); and

(c)    notwithstanding any other provision of this Agreement to the contrary, a termination or retirement of Participant's employment hereunder shall mean and be interpreted consistent with a “separation from service” within the meaning of Code Section 409A with respect to any payments hereunder that constitute a “deferral of compensation” under Code Section 409A that become due on account of such separation from service.

10

IN WITNESS WHEREOF, the Corporation has caused this Agreement to be executed by its duly authorized officer, and the Participant has also executed this Agreement and acknowledged receipt of other related materials including the Plan prospectus, all as of the Grant Date.

HESS CORPORATION

/s/ John B. Hess

John B. Hess

Chief Executive Officer

Acknowledged and Agreed to:

____________________________

11

Exhibit A

Comparison Companies and S&P Total Return Index

•Apache Corporation

•Cabot Oil & Gas Corporation

•ConocoPhillips Company

•Continental Resources, Inc.

•Devon Energy Corporation

•EOG Resources, Inc.

•EQT Corporation

•Marathon Oil Corporation

•Murphy Oil Corporation

•Occidental Petroleum Corporation

•Pioneer Natural Resources Co.

•S&P 500 Total Return Index

12

Exhibit B

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 13:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	200%
3rd	175%
4th	150%
5th	125%
6th	100%
7th	88%
8th	75%
9th	63%
10th	50%
11th	0%
12th	0%
13th	0%

13

Exhibit C-1

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 12:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	200%
3rd	175%
4th	150%
5th	125%
6th	100%
7th	83%
8th	66%
9th	50%
10th	0%
11th	0%
12th	0%

14

Exhibit C-2

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 11:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	200%
3rd	175%
4th	150%
5th	100%
6th	83%
7th	67%
8th	50%
9th	0%
10th	0%
11th	0%

15

Exhibit C-3

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 10:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	175%
3rd	150%
4th	125%
5th	100%
6th	75%
7th	50%
8th	0%
9th	0%
10th	0%

16

Exhibit C-4

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 9:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	167%
3rd	133%
4th	100%
5th	83%
6th	67%
7th	50%
8th	0%
9th	0%

17

Exhibit C-5

Percentage of Performance Shares Earned Schedule

Use this schedule if number of Comparison Companies and the S&P Total Return Index plus the Corporation is 8:

TSR Ranking	Percentage of Performance Shares Earned
1st	200%
2nd	167%
3rd	133%
4th	100%
5th	75%
6th	50%
7th	0%
8th	0%

18

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:  May 6, 2021

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:  May 6, 2021

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 March 31, 2021 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: May 6, 2021

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 March 31, 2021 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, John P. Rielly, Executive 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: May 6, 2021

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	3 Months Ended
	Mar. 31, 2021 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
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)	308,436,780
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Entity Central Index Key	0000004447
Current Fiscal Year End Date	--12-31

XML

CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Current Assets:
Cash and cash equivalents	$ 1,866	$ 1,739
Accounts receivable:
From contracts with customers	860	710
Joint venture and other	151	150
Inventories	219	378
Assets held for sale	229	0
Other current assets	197	104
Total current assets	3,522	3,081
Property, plant and equipment:
Total — at cost	30,642	30,519
Less: Reserves for depreciation, depletion, amortization and lease impairment	16,779	16,404
Property, plant and equipment — net	13,863	14,115
Operating lease right-of-use assets — net	386	426
Finance lease right-of-use assets — net	161	168
Goodwill	360	360
Deferred income taxes	41	59
Other assets	618	612
Total Assets	18,951	18,821
Current Liabilities:
Accounts payable	172	200
Accrued liabilities	1,254	1,251
Taxes payable	168	81
Current maturities of long-term debt	13	10
Current portion of operating and finance lease obligations	83	81
Total current liabilities	1,690	1,623
Long-term debt	8,273	8,286
Long-term operating lease obligations	437	478
Long-term finance lease obligations	215	220
Deferred income taxes	324	342
Asset retirement obligations	758	894
Other liabilities and deferred credits	611	643
Total Liabilities	12,308	12,486
Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized - 600,000,000 shares, Issued - 308,436,780 shares (2020: 306,980,092)	308	307
Capital in excess of par value	5,779	5,684
Retained earnings	305	130
Accumulated other comprehensive income (loss)	(776)	(755)
Total Hess Corporation stockholders’ equity	5,616	5,366
Noncontrolling interests	1,027	969
Total Equity	6,643	6,335
Total Liabilities and Equity	$ 18,951	$ 18,821

XML

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Mar. 31, 2021	Dec. 31, 2020
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)	308,436,780	306,980,092

XML

STATEMENT OF CONSOLIDATED INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Revenues and Non-Operating Income
Sales and other operating revenues	$ 1,898	$ 1,354
Other, net	21	15
Total revenues and non-operating income	1,919	1,369
Costs and Expenses
Marketing, including purchased oil and gas	518	378
Operating costs and expenses	265	303
Production and severance taxes	37	42
Exploration expenses, including dry holes and lease impairment	33	189
General and administrative expenses	94	102
Interest expense	117	113
Depreciation, depletion and amortization	396	561
Impairment	0	2,126
Total costs and expenses	1,460	3,814
Income (Loss) Before Income Taxes	459	(2,445)
Provision (benefit) for income taxes	123	(79)
Net Income (Loss)	336	(2,366)
Less: Net income (loss) attributable to noncontrolling interests	84	67
Net income (loss) attributable to Hess Corporation	$ 252	$ (2,433)
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic (in dollars per share)	$ 0.82	$ (8.00)
Diluted (in dollars per share)	$ 0.82	$ (8.00)
Weighted Average Number of Common Shares Outstanding:
Basic (in shares)	305.8	304.0
Diluted (in shares)	307.8	304.0
Common Stock Dividends Per Share (in dollars per share)	$ 0.25	$ 0.25

XML

STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ 336	$ (2,366)
Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	51	(64)
Income taxes on effect of hedge (gains) losses reclassified to income	0	0
Net effect of hedge (gains) losses reclassified to income	51	(64)
Change in fair value of cash flow hedges	(102)	990
Income taxes on change in fair value of cash flow hedges	0	0
Net change in fair value of cash flow hedges	(102)	990
Change in derivatives designated as cash flow hedges, after taxes	(51)	926
Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	14	0
Income taxes on actuarial changes in plan liabilities	0	0
(Increase) reduction in unrecognized actuarial losses, net	14	0
Amortization of net actuarial losses	16	12
Income taxes on amortization of net actuarial losses	0	0
Net effect of amortization of net actuarial losses	16	12
Change in pension and other postretirement plans, after taxes	30	12
Other Comprehensive Income (Loss)	(21)	938
Comprehensive Income (Loss)	315	(1,428)
Less: Comprehensive income (loss) attributable to noncontrolling interests	84	67
Comprehensive Income (Loss) Attributable to Hess Corporation	$ 231	$ (1,495)

XML

STATEMENT OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash Flows From Operating Activities
Net income (loss)	$ 336	$ (2,366)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	396	561
Impairment	0	2,126
Exploratory dry hole costs	0	135
Exploration lease and other impairment	4	32
Pension settlement loss	1	0
Stock compensation expense	25	29
Noncash (gains) losses on commodity derivatives, net	24	70
Provision (benefit) for deferred income taxes and other tax accruals	29	(85)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(329)	258
(Increase) decrease in inventories	159	31
Increase (decrease) in accounts payable and accrued liabilities	(127)	(263)
Increase (decrease) in taxes payable	87	(63)
Changes in other operating assets and liabilities	(14)	(20)
Net cash provided by (used in) operating activities	591	445
Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	(358)	(740)
Additions to property, plant and equipment - Midstream	(27)	(78)
Net cash provided by (used in) investing activities	(385)	(818)
Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	(10)	60
Debt with maturities of greater than 90 days – Borrowings	0	1,000
Debt with maturities of greater than 90 days - Repayments	(3)	0
Proceeds from sale of Class A shares of Hess Midstream LP	70	0
Payments on finance lease obligations	(2)	(1)
Cash dividends paid	(80)	(81)
Noncontrolling interests, net	(67)	(63)
Other, net	13	(7)
Net cash provided by (used in) financing activities	(79)	908
Net Increase (Decrease) in Cash and Cash Equivalents	127	535
Cash and Cash Equivalents at Beginning of Year	1,739	1,545
Cash and Cash Equivalents at End of Period	$ 1,866	$ 2,080

XML

STATEMENT OF CONSOLIDATED EQUITY - USD ($) $ in Millions	Total	Common Stock	Capital in Excess of Par	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Total Hess Stockholders' Equity	Noncontrolling Interests
Balance at Dec. 31, 2019	$ 9,706	$ 305	$ 5,591	$ 3,535	$ (699)	$ 8,732	$ 974
Net income (loss)	(2,366)			(2,433)		(2,433)	67
Other comprehensive income (loss)	938				938	938
Share-based compensation	39	2	42	(5)		39
Dividends on common stock	(76)			(76)		(76)
Noncontrolling interests, net	(63)						(63)
Balance at Mar. 31, 2020	8,178	307	5,633	1,021	239	7,200	978
Balance at Dec. 31, 2020	6,335	307	5,684	130	(755)	5,366	969
Net income (loss)	336			252		252	84
Other comprehensive income (loss)	(21)				(21)	(21)
Share-based compensation	40	1	39			40
Dividends on common stock	(77)			(77)		(77)
Sale of Class A shares of Hess Midstream LP	97		56			56	41
Noncontrolling interests, net	(67)						(67)
Balance at Mar. 31, 2021	$ 6,643	$ 308	$ 5,779	$ 305	$ (776)	$ 5,616	$ 1,027

XML

Basis of Presentation

3 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

1.  Basis of Presentation                    

The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of our consolidated financial position at March 31, 2021 and December 31, 2020, the consolidated results of operations for the three months ended March 31, 2021 and 2020, and consolidated cash flows for the three months ended March 31, 2021 and 2020.  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, 2020.

XML

Inventories

3 Months Ended

Mar. 31, 2021

Inventory Disclosure [Abstract]

Inventories

2.  Inventories

Inventories consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Crude oil and natural gas liquids	$	46	$	226
Materials and supplies	173		152
Total Inventories	$	219	$	378

At December 31, 2020, crude oil inventories included $164 million associated with the cost of 4.2 million barrels of crude oil transported and stored on two chartered very large crude carriers (VLCCs) for sale in Asian markets. The two VLCC cargos were sold in the first quarter of 2021.

In the first quarter of 2020, we recognized charges of $53 million ($52 million after income taxes) in Marketing, including purchased oil and gas to reflect crude oil inventories at net realizable value.

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Property, Plant and Equipment

3 Months Ended

Mar. 31, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

3.  Property, Plant and Equipment

Assets Held for Sale:

In March 2021, we entered into an agreement to sell our interests in Denmark for total consideration of $150 million with an effective date of January 1, 2021. At March 31, 2021, property, plant and equipment and operating lease right-of-use assets totaling $229 million, and asset retirement obligations and operating lease liabilities totaling $138 million, associated with our interests in Denmark were presented as Assets held for sale and as liabilities held for sale within Accrued Liabilities, respectively, in our Consolidated Balance Sheet.

Capitalized Exploratory Well Costs:  

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the three months ended March 31, 2021 (in millions):

Balance at January 1, 2021	$	459
Additions to capitalized exploratory well costs pending the determination of proved reserves	17
Balance at March 31, 2021	$	476

Capitalized exploratory well costs capitalized for greater than one year following completion of drilling were $375 million at March 31, 2021 and primarily related to:  

Guyana: Approximately 85% 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 and is conducting pre-development planning for additional phases of development beyond the three previously sanctioned development projects on the Block.

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 5% 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 one successful exploration well.  Subsurface evaluation and pre-development studies are ongoing.

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Hess Midstream LP

3 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Hess Midstream LP

4.  Hess Midstream LP

In March 2021, the Corporation received net proceeds of $70 million from the public offering of 3,450,000 Hess-owned Class A shares in Hess Midstream LP. The transaction resulted in an increase in Capital in Excess of Par of $56 million and Noncontrolling Interests of $41 million including $14 million from the change in ownership and $27 million from the recognition of a deferred tax asset due to an increase in tax basis of Hess Midstream LP's investment in Hess Midstream Operations LP. After giving effect to this transaction, the Corporation owns an approximate 46% interest in Hess Midstream LP, on a consolidated basis.

At March 31, 2021 Hess Midstream LP, a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling $1,984 million (December 31, 2020: $2,026 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream LP assets available to settle the obligations of Hess Midstream LP include cash and cash equivalents totaling $2 million (December 31, 2020: $3 million), property, plant and equipment with a carrying value of $3,095 million (December 31, 2020: $3,111 million) and an equity-method investment of $104 million (December 31, 2020: $108 million) in the Little Missouri 4 gas processing plant.

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Accrued Liabilities

3 Months Ended

Mar. 31, 2021

Payables and Accruals [Abstract]

Accrued Liabilities

5.  Accrued Liabilities

Accrued Liabilities consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Accrued capital expenditures	$	263	$	345
Accrued operating and marketing expenditures	263		325
Accrued payments to royalty and working interest owners	227		170
Liabilities held for sale	138		—
Accrued interest on debt	96		126
Accrued compensation and benefits	93		117
Current portion of asset retirement obligations	156		105
Other accruals	18		63
Total Accrued Liabilities	$	1,254	$	1,251

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Revenue

3 Months Ended

Mar. 31, 2021

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		Other (a)		E&P Total
	(In millions)
Three Months Ended March 31, 2021
Sales of our net production volumes:
Crude oil revenue	$	885	$	181	$	22	$	116	$	1,204	$	—	$	—	$	1,204
Natural gas liquids revenue	143		—		—		—		143		—		—		143
Natural gas revenue	113		—		163		3		279		—		—		279
Sales of purchased oil and gas	298		4		—		19		321		—		—		321
Intercompany revenue	—		—		—		—		—		289		(289)		—
Total revenues from contracts with customers	1,439		185		185		138		1,947		289		(289)		1,947
Other operating revenues (b)	(41)		(4)		—		(4)		(49)		—		—		(49)
Total sales and other operating revenues	$	1,398	$	181	$	185	$	134	$	1,898	$	289	$	(289)	$	1,898
Three Months Ended March 31, 2020
Sales of our net production volumes:
Crude oil revenue	$	656	$	38	$	2	$	36	$	732	$	—	$	—	$	732
Natural gas liquids revenue	49		—		—		—		49		—		—		49
Natural gas revenue	38		—		139		4		181		—		—		181
Sales of purchased oil and gas	324		1		—		—		325		—		—		325
Intercompany revenue	—		—		—		—		—		291		(291)		—
Total revenues from contracts with customers	1,067		39		141		40		1,287		291		(291)		1,287
Other operating revenues (b)	55		6		1		5		67		—		—		67
Total sales and other operating revenues	$	1,122	$	45	$	142	$	45	$	1,354	$	291	$	(291)	$	1,354

(a)Other includes our interests in Denmark and Libya.

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

There have been no significant changes to contracts with customers or composition thereof during the three months ended March 31, 2021.  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	3 Months Ended
	Mar. 31, 2021
Asset Impairment Charges [Abstract]
Impairment	7.  ImpairmentIn 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 and Tubular Bells fields 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.

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Retirement Plans

3 Months Ended

Mar. 31, 2021

Retirement Benefits [Abstract]

Retirement Plans

8. Retirement Plans

Components of net periodic pension cost consisted of the following:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Service cost	$	14	$	14
Interest cost (a)	14		18
Expected return on plan assets (a)	(50)		(45)
Amortization of unrecognized net actuarial losses (a)	15		12
Settlement loss (a)	1		—
Pension (income) expense (a)	$	(6)	$	(1)

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three months ended March 31, 2021 was income of $20 million (2020: income of $15 million).

In 2021, we expect to contribute approximately $4 million to our funded pension plans.

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Weighted Average Common Shares

3 Months Ended

Mar. 31, 2021

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 March 31,
	2021		2020
	(In millions)
Net income (loss) attributable to Hess Corporation:
Net income (loss)	$	336	$	(2,366)
Less: Net income (loss) attributable to noncontrolling interests	84		67
Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)
Weighted average number of common shares outstanding:
Basic	305.8		304.0
Effect of dilutive securities
Restricted common stock	0.8		—
Stock options	0.4		—
Performance share units	0.8		—
Diluted	307.8		304.0

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

	Three Months Ended March 31,
	2021	2020
Restricted common stock	189,000	2,015,659
Stock options	1,164,214	4,086,340
Performance share units	36,134	1,296,356

During the three months ended March 31, 2021, we granted 695,832 shares of restricted stock (2020: 1,117,009), 319,295 stock options (2020: 686,639), and 205,155 performance share units (2020: 307,999).

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Guarantees and Contingencies

3 Months Ended

Mar. 31, 2021

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 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 began in the fourth quarter of 2020. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us, and the costs will continue to be allocated amongst the parties, as they were for the Remedial Design.

From time to time, we are involved in other judicial and administrative proceedings relating to environmental matters. 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. Beginning in 2017, certain states, municipalities and private associations in California, Delaware, Maryland, Rhode Island and South Carolina separately filed lawsuits against oil, gas and coal producers, including us, for alleged damages purportedly caused by climate change. These proceedings include claims for monetary damages and injunctive relief. Beginning in 2013, various parishes in Louisiana filed suit against approximately 100 oil and gas companies, including us, alleging that the companies’ operations and activities in certain fields violated the State and Local Coastal Resource Management Act of 1978, as amended, and caused contamination, subsidence and other environmental damages to land and water bodies located in the coastal zone of Louisiana. The plaintiffs seek, among other things, the payment of the costs necessary to clear, re-vegetate and otherwise restore the allegedly impacted areas. The ultimate impact of such climate and other aforementioned environmental 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.

We are also involved in other judicial and administrative proceedings from time to time in addition to the matters described above, including claims related to post-production deductions from royalty payments. 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

3 Months Ended

Mar. 31, 2021

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 March 31, 2021
Sales and Other Operating Revenues - Third parties	$	1,898	$	—	$	—	$	—	$	1,898
Intersegment Revenues	—		289		—		(289)		—
Sales and Other Operating Revenues	$	1,898	$	289	$	—	$	(289)	$	1,898
Net Income (Loss) attributable to Hess Corporation	$	308	$	75	$	(131)	$	—	$	252
Depreciation, Depletion and Amortization	355		40		1		—		396
Provision (Benefit) for Income Taxes	120		3		—		—		123
Capital Expenditures	280		23		—		—		303
For the Three Months Ended March 31, 2020
Sales and Other Operating Revenues - Third parties	$	1,354	$	—	$	—	$	—	$	1,354
Intersegment Revenues	—		291		—		(291)		—
Sales and Other Operating Revenues	$	1,354	$	291	$	—	$	(291)	$	1,354
Net Income (Loss) attributable to Hess Corporation	$	(2,371)	$	61	$	(123)	$	—	$	(2,433)
Depreciation, Depletion and Amortization	521		38		2		—		561
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(77)		2		(4)		—		(79)
Capital Expenditures	609		57		—		—		666

Identifiable assets by operating segment were as follows:

	March 31, 2021		December 31, 2020
	(In millions)
Exploration and Production	$	13,764	$	13,688
Midstream	3,586		3,599
Corporate, Interest and Other	1,601		1,534
Total	$	18,951	$	18,821

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Financial Risk Management Activities

3 Months Ended

Mar. 31, 2021

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. 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 or establish a floor price for a portion of our crude oil or natural gas production. Swaps may also be used to fix the difference between current selling prices and forward selling prices in periods of contango for crude oil production that will be stored and sold in the future. Forward contracts may also be used to purchase certain currencies in which we conduct business with the intent of reducing exposure to foreign currency fluctuations. At March 31, 2021, these forward contracts relate to the British Pound, Danish Krone, Canadian Dollar and Malaysian Ringgit. 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:

	March 31, 2021		December 31, 2020
	(In millions)
Commodity - crude oil put options (millions of barrels)	41.3		27.4
Foreign exchange forwards	$	121	$	163
Interest rate swaps	$	100	$	100

As of March 31, 2021, we have purchased West Texas Intermediate (WTI) put options of 120,000 barrels of oil per day (bopd) with an average monthly floor price of $55 per barrel and Brent put options of 30,000 bopd with an average monthly floor price of $60 per barrel for the remainder of 2021.

The table below reflects the fair values of risk management derivative instruments.

	Assets		Liabilities
	(In millions)
March 31, 2021
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	154	$	—
Interest rate swaps	4		—
Total derivative contracts designated as hedging instruments	158		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(2)
Total derivative contracts not designated as hedging instruments	—		(2)
Gross fair value of derivative contracts	158		(2)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	158	$	(2)
December 31, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	64	$	—
Crude oil swaps	—		(54)
Interest rate swaps	5		—
Total derivative contracts designated as hedging instruments	69		(54)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	69		(55)
Gross amounts offset in the Consolidated Balance Sheet	(13)		13
Net Amounts Presented in the Consolidated Balance Sheet	$	56	$	(42)

During the first quarter of 2021, we completed the sale of 4.2 million barrels of Bakken crude oil transported and stored on two VLCCs during 2020 for sale in Asian markets. We recognized net losses of $4 million from crude oil hedging contracts associated with the VLCC volumes in the first quarter of 2021.

The fair value of our crude oil put options and crude oil swaps is presented within Other current assets and Accrued liabilities, respectively, in our Consolidated Balance Sheet. The fair value of our interest rate swaps is presented within Other assets in our Consolidated Balance Sheet. The fair value of our foreign exchange forwards is presented within Accrued liabilities in our Consolidated Balance Sheet. 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 decreased Sales and other operating revenues by $51 million in the first quarter of 2021, including hedge contracts associated with the VLCC transactions, and increased Sales and other operating revenues by $64 million in the first quarter of 2020. At March 31, 2021, pre-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding crude oil price hedging contracts were $47 million, all of which will be reclassified into earnings during the remainder of 2021 as the originally hedged crude oil sales are recognized in earnings.

Interest rate swaps designated as fair value hedges:  At March 31, 2021 and December 31, 2020, 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 months ended March 31, 2021, the change in fair value of interest rate swaps was a decrease in the asset of $1 million (2020 Q1: increase in the asset of $5 million) 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 $1 million in the three months ended March 31, 2021 (2020 Q1: $1 million loss).  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 losses of $1 million in the three months ended March 31, 2021 (2020 Q1: $2 million gain).

Fair Value Measurement:At March 31, 2021, our total long-term debt, which was substantially comprised of fixed rate debt instruments, had a carrying value of $8,286 million and a fair value of $9,381 million, based on Level 2 inputs in the fair value measurement hierarchy. We also have short-term financial instruments, primarily cash equivalents, accounts receivable, and accounts payable, for which the carrying value approximated fair value at March 31, 2021 and December 31, 2020.

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Subsequent Events

3 Months Ended

Mar. 31, 2021

Subsequent Events [Abstract]

Subsequent Events

13.  Subsequent Events

On April 30, 2021, we completed the sale of our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312 million with an effective date of March 1, 2021. The sale included approximately 78,700 net acres, which are located in the southernmost portion of the Corporation's Bakken position and are not connected to Hess Midstream LP infrastructure. Net production from the acreage during the first quarter of 2021 was approximately 4,500 barrels of oil equivalent per day (boepd).

On April 13, 2021, we amended the Corporation's fully undrawn $3.5 billion revolving credit facility by extending the facility's expiration date for one year to May 2024 and incorporating customary provisions for the eventual replacement of the London Interbank Offered Rate (LIBOR).

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Inventories (Tables)

3 Months Ended

Mar. 31, 2021

Inventory Disclosure [Abstract]

Inventories

Inventories consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Crude oil and natural gas liquids	$	46	$	226
Materials and supplies	173		152
Total Inventories	$	219	$	378

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Property, Plant and Equipment (Tables)

3 Months Ended

Mar. 31, 2021

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 three months ended March 31, 2021 (in millions):

Balance at January 1, 2021	$	459
Additions to capitalized exploratory well costs pending the determination of proved reserves	17
Balance at March 31, 2021	$	476

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Accrued Liabilities (Tables)

3 Months Ended

Mar. 31, 2021

Payables and Accruals [Abstract]

Schedule of Accrued Liabilities

Accrued Liabilities consisted of the following:

	March 31, 2021		December 31, 2020
	(In millions)
Accrued capital expenditures	$	263	$	345
Accrued operating and marketing expenditures	263		325
Accrued payments to royalty and working interest owners	227		170
Liabilities held for sale	138		—
Accrued interest on debt	96		126
Accrued compensation and benefits	93		117
Current portion of asset retirement obligations	156		105
Other accruals	18		63
Total Accrued Liabilities	$	1,254	$	1,251

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Revenue (Tables)

3 Months Ended

Mar. 31, 2021

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		Other (a)		E&P Total
	(In millions)
Three Months Ended March 31, 2021
Sales of our net production volumes:
Crude oil revenue	$	885	$	181	$	22	$	116	$	1,204	$	—	$	—	$	1,204
Natural gas liquids revenue	143		—		—		—		143		—		—		143
Natural gas revenue	113		—		163		3		279		—		—		279
Sales of purchased oil and gas	298		4		—		19		321		—		—		321
Intercompany revenue	—		—		—		—		—		289		(289)		—
Total revenues from contracts with customers	1,439		185		185		138		1,947		289		(289)		1,947
Other operating revenues (b)	(41)		(4)		—		(4)		(49)		—		—		(49)
Total sales and other operating revenues	$	1,398	$	181	$	185	$	134	$	1,898	$	289	$	(289)	$	1,898
Three Months Ended March 31, 2020
Sales of our net production volumes:
Crude oil revenue	$	656	$	38	$	2	$	36	$	732	$	—	$	—	$	732
Natural gas liquids revenue	49		—		—		—		49		—		—		49
Natural gas revenue	38		—		139		4		181		—		—		181
Sales of purchased oil and gas	324		1		—		—		325		—		—		325
Intercompany revenue	—		—		—		—		—		291		(291)		—
Total revenues from contracts with customers	1,067		39		141		40		1,287		291		(291)		1,287
Other operating revenues (b)	55		6		1		5		67		—		—		67
Total sales and other operating revenues	$	1,122	$	45	$	142	$	45	$	1,354	$	291	$	(291)	$	1,354

(a)Other includes our interests in Denmark and Libya.

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

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Retirement Plans (Tables)

3 Months Ended

Mar. 31, 2021

Retirement Benefits [Abstract]

Components of Net Periodic Pension Cost

Components of net periodic pension cost consisted of the following:

	Three Months Ended March 31,
	2021		2020
	(In millions)
Service cost	$	14	$	14
Interest cost (a)	14		18
Expected return on plan assets (a)	(50)		(45)
Amortization of unrecognized net actuarial losses (a)	15		12
Settlement loss (a)	1		—
Pension (income) expense (a)	$	(6)	$	(1)

(a)  Net non-service pension cost included in Other, net in the Statement of Consolidated Income for the three months ended March 31, 2021 was income of $20 million (2020: income of $15 million).

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Weighted Average Common Shares (Tables)

3 Months Ended

Mar. 31, 2021

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 March 31,
	2021		2020
	(In millions)
Net income (loss) attributable to Hess Corporation:
Net income (loss)	$	336	$	(2,366)
Less: Net income (loss) attributable to noncontrolling interests	84		67
Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)
Weighted average number of common shares outstanding:
Basic	305.8		304.0
Effect of dilutive securities
Restricted common stock	0.8		—
Stock options	0.4		—
Performance share units	0.8		—
Diluted	307.8		304.0

Summary of Antidilutive Shares Excluded from Computation of Diluted Shares

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

	Three Months Ended March 31,
	2021	2020
Restricted common stock	189,000	2,015,659
Stock options	1,164,214	4,086,340
Performance share units	36,134	1,296,356

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2021

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 March 31, 2021
Sales and Other Operating Revenues - Third parties	$	1,898	$	—	$	—	$	—	$	1,898
Intersegment Revenues	—		289		—		(289)		—
Sales and Other Operating Revenues	$	1,898	$	289	$	—	$	(289)	$	1,898
Net Income (Loss) attributable to Hess Corporation	$	308	$	75	$	(131)	$	—	$	252
Depreciation, Depletion and Amortization	355		40		1		—		396
Provision (Benefit) for Income Taxes	120		3		—		—		123
Capital Expenditures	280		23		—		—		303
For the Three Months Ended March 31, 2020
Sales and Other Operating Revenues - Third parties	$	1,354	$	—	$	—	$	—	$	1,354
Intersegment Revenues	—		291		—		(291)		—
Sales and Other Operating Revenues	$	1,354	$	291	$	—	$	(291)	$	1,354
Net Income (Loss) attributable to Hess Corporation	$	(2,371)	$	61	$	(123)	$	—	$	(2,433)
Depreciation, Depletion and Amortization	521		38		2		—		561
Impairment	2,126		—		—		—		2,126
Provision (Benefit) for Income Taxes	(77)		2		(4)		—		(79)
Capital Expenditures	609		57		—		—		666

Identifiable assets by operating segment were as follows:

	March 31, 2021		December 31, 2020
	(In millions)
Exploration and Production	$	13,764	$	13,688
Midstream	3,586		3,599
Corporate, Interest and Other	1,601		1,534
Total	$	18,951	$	18,821

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Financial Risk Management Activities (Tables)

3 Months Ended

Mar. 31, 2021

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:

	March 31, 2021		December 31, 2020
	(In millions)
Commodity - crude oil put options (millions of barrels)	41.3		27.4
Foreign exchange forwards	$	121	$	163
Interest rate swaps	$	100	$	100

Fair Values of Financial Risk Management Derivative Instruments

The table below reflects the fair values of risk management derivative instruments.

	Assets		Liabilities
	(In millions)
March 31, 2021
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	154	$	—
Interest rate swaps	4		—
Total derivative contracts designated as hedging instruments	158		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(2)
Total derivative contracts not designated as hedging instruments	—		(2)
Gross fair value of derivative contracts	158		(2)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	158	$	(2)
December 31, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	64	$	—
Crude oil swaps	—		(54)
Interest rate swaps	5		—
Total derivative contracts designated as hedging instruments	69		(54)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	69		(55)
Gross amounts offset in the Consolidated Balance Sheet	(13)		13
Net Amounts Presented in the Consolidated Balance Sheet	$	56	$	(42)

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Inventories - Inventories (Detail) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 46	$ 226
Materials and supplies	173	152
Total Inventories	$ 219	$ 378

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Inventories - Additional Information (Detail) bbl in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) vlcc	Mar. 31, 2020 USD ($)	Dec. 31, 2020 USD ($) vlcc bbl
Inventory [Line Items]
Cost of crude oil	$ 46		$ 226
Charges related to inventories		$ 53
Charges related to inventories, after income taxes		$ 52
Very Large Crude Carriers (VLCCs)
Inventory [Line Items]
Cost of crude oil			$ 164
Crude oil loaded in very large crude carriers (in barrels of oil) | bbl			4.2
Number of very large crude carriers | vlcc			2
Number of VLCC's cargos sold | vlcc	2

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Property, Plant, and Equipment - Assets Held for Sale - Additional Information (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Long Lived Assets Held-for-Sale [Line Items]
Assets held for sale	$ 229	$ 0
Liabilities held for sale	138	$ 0
Denmark
Long Lived Assets Held-for-Sale [Line Items]
Assets held for sale	229
Liabilities held for sale	138
Disposed of by Sale | Denmark
Long Lived Assets Held-for-Sale [Line Items]
Expected proceeds from divestiture of businesses and interest in affiliates	$ 150

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Property, Plant and Equipment - Net Changes in Capitalized Exploratory Well Costs (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Property, Plant and Equipment [Abstract]
Beginning balance	$ 459
Additions to capitalized exploratory well costs pending the determination of proved reserves	17
Ending balance	$ 476

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Property, Plant and Equipment - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) well
Capitalized Exploratory Well Costs [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $	$ 375
Stabroek Block, Offshore Guyana
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	85.00%
Project interest percentage	30.00%
JDA, Gulf of Thailand
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	10.00%
Project interest percentage	50.00%
Number of successful exploration wells drilled	3
North Malay Basin, Offshore Peninsular Malaysia
Capitalized Exploratory Well Costs [Line Items]
Capitalized well costs percentage	5.00%
Project interest percentage	50.00%
Number of successful exploration wells drilled	1

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Hess Midstream LP (Detail) - USD ($) shares in Thousands, $ in Millions	1 Months Ended	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Variable Interest Entity [Line Items]
Proceeds from sale of Class A shares of Hess Midstream LP	$ 70	$ 70	$ 0
Number of Class A shares of subsidiary public offering (in shares)	3,450
Sale of Class A shares of Hess Midstream LP		97
Liabilities	$ 12,308	12,308		$ 12,486
Cash and cash equivalents	1,866	1,866		1,739
Property, plant and equipment, net	$ 13,863	13,863		14,115
Capital in Excess of Par
Variable Interest Entity [Line Items]
Sale of Class A shares of Hess Midstream LP		56
Noncontrolling Interests
Variable Interest Entity [Line Items]
Sale of Class A shares of Hess Midstream LP		41
Noncontrolling Interests | Change In Ownership
Variable Interest Entity [Line Items]
Sale of Class A shares of Hess Midstream LP		14
Noncontrolling Interests | Recognition of Deferred Tax Asset
Variable Interest Entity [Line Items]
Sale of Class A shares of Hess Midstream LP		27
Hess Midstream LP
Variable Interest Entity [Line Items]
Percent interest in consolidated entity	46.00%
Cash and cash equivalents	$ 2	2		3
Property, plant and equipment, net	3,095	3,095		3,111
Hess Midstream LP | Nonrecourse
Variable Interest Entity [Line Items]
Liabilities	1,984	1,984		2,026
Hess Midstream LP | Little Missouri Four
Variable Interest Entity [Line Items]
Equity method investment	$ 104	$ 104		$ 108

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Accrued Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Payables and Accruals [Abstract]
Accrued capital expenditures	$ 263	$ 345
Accrued operating and marketing expenditures	263	325
Accrued payments to royalty and working interest owners	227	170
Liabilities held for sale	138	0
Accrued interest on debt	96	126
Accrued compensation and benefits	93	117
Current portion of asset retirement obligations	156	105
Other accruals	18	63
Accrued liabilities	$ 1,254	$ 1,251

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Revenue (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 1,947	$ 1,287
Other operating revenues	(49)	67
Total sales and other operating revenues	1,898	1,354
Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,204	732
Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	49
Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	279	181
Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	321	325
Exploration and Production
Disaggregation of Revenue [Line Items]
Total sales and other operating revenues	1,898	1,354
Exploration and Production | Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,204	732
Exploration and Production | Crude oil revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	885	656
Exploration and Production | Crude oil revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	181	38
Exploration and Production | Crude oil revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	22	2
Exploration and Production | Crude oil revenue | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	116	36
Exploration and Production | Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	49
Exploration and Production | Natural gas liquids revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	143	49
Exploration and Production | Natural gas liquids revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Exploration and Production | Natural gas liquids revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Exploration and Production | Natural gas liquids revenue | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Exploration and Production | Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	279	181
Exploration and Production | Natural gas revenue | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	113	38
Exploration and Production | Natural gas revenue | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Exploration and Production | Natural gas revenue | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	163	139
Exploration and Production | Natural gas revenue | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3	4
Exploration and Production | Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	321	325
Exploration and Production | Sales of purchased oil and gas | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	298	324
Exploration and Production | Sales of purchased oil and gas | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4	1
Exploration and Production | Sales of purchased oil and gas | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Exploration and Production | Sales of purchased oil and gas | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	19	0
Midstream
Disaggregation of Revenue [Line Items]
Total sales and other operating revenues	0	0
Midstream | Crude oil revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Midstream | Natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Midstream | Natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Midstream | Sales of purchased oil and gas
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Exploration and Production
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,947	1,287
Other operating revenues	(49)	67
Total sales and other operating revenues	1,898	1,354
Operating Segments | Exploration and Production | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,439	1,067
Other operating revenues	(41)	55
Total sales and other operating revenues	1,398	1,122
Operating Segments | Exploration and Production | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	185	39
Other operating revenues	(4)	6
Total sales and other operating revenues	181	45
Operating Segments | Exploration and Production | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	185	141
Other operating revenues	0	1
Total sales and other operating revenues	185	142
Operating Segments | Exploration and Production | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	138	40
Other operating revenues	(4)	5
Total sales and other operating revenues	134	45
Operating Segments | Midstream
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	289	291
Other operating revenues	0	0
Total sales and other operating revenues	289	291
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(289)	(291)
Other operating revenues	0	0
Total sales and other operating revenues	(289)	(291)
Eliminations | Exploration and Production
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Total sales and other operating revenues	0	0
Eliminations | Exploration and Production | United States
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Exploration and Production | Guyana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Exploration and Production | Malaysia & JDA
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Exploration and Production | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Midstream
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	289	291
Total sales and other operating revenues	$ 289	$ 291

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Impairment (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Impairments [Line Items]
Impairment charge, pre-tax	$ 0	$ 2,126
Oil and Gas Properties
Impairments [Line Items]
Impairment charge, pre-tax		2,100
Impairment charge, after income taxes		2,000
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
	Mar. 31, 2021	Mar. 31, 2020
Retirement Benefits [Abstract]
Service cost	$ 14	$ 14
Interest cost	14	18
Expected return on plan assets	(50)	(45)
Amortization of unrecognized net actuarial losses	15	12
Settlement loss	1	0
Pension (income) expense	(6)	(1)
Net non-service pension (income) costs included in other, net	$ 20	$ (15)

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Retirement Plans - Additional Information (Detail) $ in Millions	Mar. 31, 2021 USD ($)
Retirement Benefits [Abstract]
Corporation's estimated contribution for funded pension plans in current fiscal year	$ 4

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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
	Mar. 31, 2021	Mar. 31, 2020
Net income (loss) attributable to Hess Corporation:
Net income (loss)	$ 336	$ (2,366)
Less: Net income (loss) attributable to noncontrolling interests	84	67
Net Income (Loss) attributable to Hess Corporation	$ 252	$ (2,433)
Weighted average number of common shares outstanding:
Basic (in shares)	305.8	304.0
Diluted (in shares)	307.8	304.0
Restricted common stock
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.8	0.0
Stock options
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.4	0.0
Performance share units
Weighted average number of common shares outstanding:
Effect of dilutive securities (in shares)	0.8	0.0

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Weighted Average Common Shares - Antidilutive Shares Excluded from Computation of Diluted Shares (Detail) - shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Restricted common stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	189,000	2,015,659
Stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	1,164,214	4,086,340
Performance share units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive shares excluded from computation of diluted shares (in shares)	36,134	1,296,356

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Weighted Average Common Shares - Additional Information (Detail) - shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Earnings Per Share [Abstract]
Shares granted, restricted stock (in shares)	695,832	1,117,009
Shares granted, stock options (in shares)	319,295	686,639
Shares granted, performance share units (in shares)	205,155	307,999

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Guarantees and Contingencies (Detail) $ in Millions		1 Months Ended
	Mar. 04, 2016 USD ($)	Mar. 31, 2014 USD ($)	Mar. 31, 2021 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)	3 Months Ended
	Mar. 31, 2021 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
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 1,898	$ 1,354
Net Income (Loss) attributable to Hess Corporation	252	(2,433)
Depreciation, depletion and amortization	396	561
Impairment		2,126
Provision (benefit) for income taxes	123	(79)
Capital Expenditures	303	666
Assets	18,951		$ 18,821
Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,898	1,354
Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0
Operating Segments | Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,898	1,354
Net Income (Loss) attributable to Hess Corporation	308	(2,371)
Depreciation, depletion and amortization	355	521
Impairment		2,126
Provision (benefit) for income taxes	120	(77)
Capital Expenditures	280	609
Assets	13,764		13,688
Operating Segments | Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	289	291
Net Income (Loss) attributable to Hess Corporation	75	61
Depreciation, depletion and amortization	40	38
Impairment		0
Provision (benefit) for income taxes	3	2
Capital Expenditures	23	57
Assets	3,586		3,599
Corporate, Interest and Other
Segment Reporting Information [Line Items]
Net Income (Loss) attributable to Hess Corporation	(131)	(123)
Depreciation, depletion and amortization	1	2
Impairment		0
Provision (benefit) for income taxes	0	(4)
Capital Expenditures	0	0
Assets	1,601		$ 1,534
Eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	(289)	(291)
Net Income (Loss) attributable to Hess Corporation	0	0
Depreciation, depletion and amortization	0	0
Impairment		0
Provision (benefit) for income taxes	0	0
Capital Expenditures	0	0
Eliminations | Exploration and Production
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0
Eliminations | Midstream
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 289	$ 291

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Financial Risk Management Activities - Notional Amounts of Outstanding Financial Risk Management Derivative Contracts (Detail) MMBbls in Millions	Mar. 31, 2021 USD ($) MMBbls	Dec. 31, 2020 USD ($) MMBbls
Commodity Derivative Contracts
Derivative [Line Items]
Commodity - crude oil | MMBbls	41.3	27.4
Foreign Exchange Forwards
Derivative [Line Items]
Outstanding gross notional amount	$ 121,000,000	$ 163,000,000
Interest Rate Swaps
Derivative [Line Items]
Outstanding gross notional amount	$ 100,000,000	$ 100,000,000

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Financial Risk Management Activities - Fair Values of Financial Risk Management Derivative Instruments (Detail) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	$ 158	$ 69
Liabilities - Gross fair value of derivative contracts	(2)	(55)
Gross amounts offset in the Consolidated Balance Sheet	0	(13)
Gross amounts offset in the Consolidated Balance Sheet	0	13
Derivative assets	158	56
Derivative liability	(2)	(42)
Derivative Contracts Designated as Hedging Instruments:
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	158	69
Liabilities - Gross fair value of derivative contracts	0	(54)
Derivative Contracts Designated as Hedging Instruments: | Crude Oil Put Options
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	154	64
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Designated as Hedging Instruments: | Crude Oil Swaps
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts		0
Liabilities - Gross fair value of derivative contracts		(54)
Derivative Contracts Designated as Hedging Instruments: | Interest Rate Swaps
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	4	5
Liabilities - Gross fair value of derivative contracts	0	0
Derivative Contracts Not Designated as Hedging Instruments:
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	0	0
Liabilities - Gross fair value of derivative contracts	(2)	(1)
Derivative Contracts Not Designated as Hedging Instruments: | Foreign Exchange Forwards
Derivatives, Fair Value [Line Items]
Assets - Gross fair value of derivative contracts	0	0
Liabilities - Gross fair value of derivative contracts	$ (2)	$ (1)

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Financial Risk Management Activities - Additional Information (Detail) bbl in Millions, MMBbls in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) MMBbls bbl / d vlcc $ / bbl bbl	Mar. 31, 2020 USD ($)	Dec. 31, 2020 MMBbls
Very Large Crude Carriers (VLCCs)
Derivative Instruments, Gain (Loss) [Line Items]
Crude oil sold (in barrels of oil) | bbl	4.2
Number of VLCC's cargos sold | vlcc	2
Crude Oil Put Options | West Texas Intermediate | Derivative Activity - Purchased
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount of crude oil | bbl / d	120,000
Average monthly floor price (US dollar per barrel) | $ / bbl	55
Crude Oil Put Options | Brent | Derivative Activity - Purchased
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount of crude oil | bbl / d	30,000
Average monthly floor price (US dollar per barrel) | $ / bbl	60
Commodity Derivative Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount of crude oil | MMBbls	41.3		27.4
Commodity Derivative Contracts | Derivative Contracts Designated as Hedging Instruments: | Designated as Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) from crude oil hedging contracts | $	$ (51)	$ 64
Commodity Derivative Contracts | Very Large Crude Carriers (VLCCs) | Derivative Contracts Designated as Hedging Instruments: | Designated as Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) from crude oil hedging contracts | $	$ (4)

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Financial Risk Management Activities - Derivative Contracts - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Interest Rate Swaps
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding gross notional amount	$ 100,000,000		$ 100,000,000
Foreign Exchange Forwards
Derivative Instruments, Gain (Loss) [Line Items]
Outstanding gross notional amount	121,000,000		163,000,000
Derivative Contracts Designated as Hedging Instruments: | Commodity Derivative Contracts | Designated as Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Increase (decrease) in sales and other operating revenues due to hedging instruments	(51,000,000)	$ 64,000,000
Pre-tax deferred income (losses) in Accumulated other comprehensive income (loss) to be reclassified into earnings within the next 12 months	(47,000,000)
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
Unrealized change in fair value of interest rate swaps - (increase in derivative asset) decrease in derivative liability	(1,000,000)	5,000,000
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	(1,000,000)	(1,000,000)
Net gains (losses) on foreign exchange contracts not designated as hedging instruments	$ (1,000,000)	$ 2,000,000

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Financial Risk Management Activities - Fair Value Measurements - Additional Information (Detail) $ in Millions	Mar. 31, 2021 USD ($)
Fair Value Disclosures [Abstract]
Long-term debt	$ 8,286
Long-term debt, fair value	$ 9,381

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Subsequent Events (Details) $ in Millions		3 Months Ended
	Apr. 30, 2021 USD ($) a	Mar. 31, 2021 Boe	Apr. 13, 2021 USD ($)
Little Knife and Murphy Creek | Disposed of by Sale
Subsequent Event [Line Items]
Net production from acreage sold | Boe		4,500
Subsequent Event | Little Knife and Murphy Creek | Disposed of by Sale
Subsequent Event [Line Items]
Consideration received from the sale of working interests in oil and gas properties	$ 312
Developed and undeveloped acreage sold | a	78,700
Subsequent Event | Hess Corp Revolving Credit Facility
Subsequent Event [Line Items]
Line of credit facility, maximum borrowing capacity			$ 3,500