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~~2022


☐						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,~~2022, there were ~~308,436,780~~311,262,547 shares of Common Stock outstanding.

HESS CORPORATION

Form 10-Q

TABLE OF CONTENTS


Item No.	Item No.		Page Number	Item No.		Page Number
		PART I - FINANCIAL INFORMATION			PART I - FINANCIAL INFORMATION
1.	1.	Financial Statements (Unaudited)		1.	Financial Statements (Unaudited)
		Consolidated Balance Sheet at March 3 1 , 202 1 , and December 31, 20 20	2		Consolidated Balance Sheet at March 3 1 , 202 2 , and December 31, 202 1	2
		Statement of Consolidated Income for the Three Months Ended March 3 1 , 202 1 , and 20 20	3		Statement of Consolidated Income for the Three Months Ended March 3 1 , 202 2 , and 202 1	3
		Statement of Consolidated Comprehensive Income for the Three Months Ended March 3 1 , 202 1 , and 20 20	4		Statement of Consolidated Comprehensive Income for the Three Months Ended March 3 1 , 202 2 , and 202 1	4
		Statement of Consolidated Cash Flows for the Three Months Ended March 3 1 , 202 1 , and 20 20	5		Statement of Consolidated Cash Flows for the Three Months Ended March 3 1 , 202 2 , and 202 1	5
		Statement of Consolidated Equity for the Three Months Ended March 3 1 , 202 1 , and 20 20	6		Statement of Consolidated Equity for the Three Months Ended March 3 1 , 202 2 , and 202 1	6
		Notes to Consolidated Financial Statements (Unaudited)	7		Notes to Consolidated Financial Statements (Unaudited)	7
		Note 1 - Basis of Presentation	7		Note 1 - Basis of Presentation	7
		Note 2 - Inventories	7		Note 2 - Inventories	7
		Note 3 - Property, Plant and Equipment	7		Note 3 - Property, Plant and Equipment	7
		Note 4 - Hess Midstream LP	8		Note 4 - Hess Midstream LP	8
		Note 5 - Accrued Liabilities	8		Note 5 - Accrued Liabilities	8
		Note 6 - Revenue	9		Note 6 - Debt	8
		Note 7 - Impairment	9		Note 7 - Revenue	9
		Note 8 - Retirement Plans	10		Note 8 - Retirement Plans	9
		Note 9 - Weighted Average Common Shares	10		Note 9 - Weighted Average Common Shares	10
		Note 1 0 - Guarantees and Contingencies	11		Note 1 0 - Guarantees and Contingencies	10
		Note 1 1 - Segment Information	12		Note 1 1 - Segment Information	12
		Note 1 2 - Financial Risk Management Activities	13		Note 1 2 - Financial Risk Management Activities	13
		Note 1 3 - Subsequent Events	15		Note 1 3 - Subsequent Events	14

2.	2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	16	2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	15
3.	3.	Quantitative and Qualitative Disclosures about Market Risk	31	3.	Quantitative and Qualitative Disclosures about Market Risk	28
4.	4.	Controls and Procedures	31	4.	Controls and Procedures	28

		PART II - OTHER INFORMATION			PART II - OTHER INFORMATION
1.	1.	Legal Proceedings	32	1.	Legal Proceedings	29
6.	6.	Exhibits	33	6.	Exhibits	30
		Signatures	34		Signatures	31

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			March 31, 2022		December 31, 2021

		(In millions, except share amounts)					(In millions, except share amounts)
Assets	Assets					Assets
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	1,866	$	1,739	Cash and cash equivalents	$	1,370	$	2,713
Accounts receivable:	Accounts receivable:					Accounts receivable:
From contracts with customers	From contracts with customers	860		710		From contracts with customers	1,388		1,062
Joint venture and other	Joint venture and other	151		150		Joint venture and other	136		149
Inventories	Inventories	219		378		Inventories	243		223
Assets held for sale		229		0
Other current assets	Other current assets	197		104		Other current assets	129		199
Total current assets	Total current assets	3,522		3,081		Total current assets	3,266		4,346
Property, plant and equipment:	Property, plant and equipment:					Property, plant and equipment:
Total — at cost	Total — at cost	30,642		30,519		Total — at cost	31,782		31,178
Less: Reserves for depreciation, depletion, amortization and lease impairment	Less: Reserves for depreciation, depletion, amortization and lease impairment	16,779		16,404		Less: Reserves for depreciation, depletion, amortization and lease impairment	17,293		16,996
Property, plant and equipment — net	Property, plant and equipment — net	13,863		14,115		Property, plant and equipment — net	14,489		14,182
Operating lease right-of-use assets — net	Operating lease right-of-use assets — net	386		426		Operating lease right-of-use assets — net	343		352
Finance lease right-of-use assets — net	Finance lease right-of-use assets — net	161		168		Finance lease right-of-use assets — net	140		144
Goodwill	Goodwill	360		360		Goodwill	360		360
Deferred income taxes	Deferred income taxes	41		59		Deferred income taxes	65		71
Post-retirement benefit assets						Post-retirement benefit assets	412		409
Other assets	Other assets	618		612		Other assets	723		651
Total Assets	Total Assets	$	18,951	$	18,821	Total Assets	$	19,798	$	20,515
Liabilities	Liabilities					Liabilities
Current Liabilities:	Current Liabilities:					Current Liabilities:
Accounts payable	Accounts payable	$	172	$	200	Accounts payable	$	312	$	220
Accrued liabilities	Accrued liabilities	1,254		1,251		Accrued liabilities	1,749		1,710
Taxes payable	Taxes payable	168		81		Taxes payable	129		528
Current maturities of long-term debt		13		10
Current portion of long-term debt						Current portion of long-term debt	22		517
Current portion of operating and finance lease obligations	Current portion of operating and finance lease obligations	83		81		Current portion of operating and finance lease obligations	91		89
Total current liabilities	Total current liabilities	1,690		1,623		Total current liabilities	2,303		3,064
Long-term debt	Long-term debt	8,273		8,286		Long-term debt	7,934		7,941
Long-term operating lease obligations	Long-term operating lease obligations	437		478		Long-term operating lease obligations	381		394
Long-term finance lease obligations	Long-term finance lease obligations	215		220		Long-term finance lease obligations	195		200
Deferred income taxes	Deferred income taxes	324		342		Deferred income taxes	416		383
Asset retirement obligations	Asset retirement obligations	758		894		Asset retirement obligations	1,036		1,005
Other liabilities and deferred credits	Other liabilities and deferred credits	611		643		Other liabilities and deferred credits	485		502
Total Liabilities	Total Liabilities	12,308		12,486		Total Liabilities	12,750		13,489
Equity	Equity					Equity
Hess Corporation stockholders’ equity:	Hess Corporation stockholders’ equity:					Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized — 600,000,000 shares	Common stock, par value $1.00; Authorized — 600,000,000 shares					Common stock, par value $1.00; Authorized — 600,000,000 shares
Issued — 308,436,780 shares (2020: 306,980,092)		308		307
Issued 311,262,547 shares (2021: 309,744,953)						Issued 311,262,547 shares (2021: 309,744,953)	311		310
Capital in excess of par value	Capital in excess of par value	5,779		5,684		Capital in excess of par value	6,083		6,017
Retained earnings	Retained earnings	305		130		Retained earnings	680		379
Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss)	(776)		(755)		Accumulated other comprehensive income (loss)	(766)		(406)
Total Hess Corporation stockholders’ equity	Total Hess Corporation stockholders’ equity	5,616		5,366		Total Hess Corporation stockholders’ equity	6,308		6,300
Noncontrolling interests	Noncontrolling interests	1,027		969		Noncontrolling interests	740		726
Total Equity	Total Equity	6,643		6,335		Total Equity	7,048		7,026
Total Liabilities and Equity	Total Liabilities and Equity	$	18,951	$	18,821	Total Liabilities and Equity	$	19,798	$	20,515

See accompanying Notes to Consolidated Financial Statements.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED INCOME (UNAUDITED)


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions, except per share amounts)					(In millions, except per share amounts)
Revenues and Non-Operating Income	Revenues and Non-Operating Income					Revenues and Non-Operating Income
Sales and other operating revenues	Sales and other operating revenues	$	1,898	$	1,354	Sales and other operating revenues	$	2,313	$	1,898

Gains on asset sales, net						Gains on asset sales, net	22		—
Other, net	Other, net	21		15		Other, net	36		21
Total revenues and non-operating income	Total revenues and non-operating income	1,919		1,369		Total revenues and non-operating income	2,371		1,919
Costs and Expenses	Costs and Expenses					Costs and Expenses
Marketing, including purchased oil and gas	Marketing, including purchased oil and gas	518		378		Marketing, including purchased oil and gas	682		518
Operating costs and expenses	Operating costs and expenses	265		303		Operating costs and expenses	313		265
Production and severance taxes	Production and severance taxes	37		42		Production and severance taxes	61		37
Exploration expenses, including dry holes and lease impairment	Exploration expenses, including dry holes and lease impairment	33		189		Exploration expenses, including dry holes and lease impairment	43		33
General and administrative expenses	General and administrative expenses	94		102		General and administrative expenses	110		94
Interest expense	Interest expense	117		113		Interest expense	123		117
Depreciation, depletion and amortization	Depreciation, depletion and amortization	396		561		Depreciation, depletion and amortization	337		396
Impairment		0		2,126

Total costs and expenses	Total costs and expenses	1,460		3,814		Total costs and expenses	1,669		1,460
Income (Loss) Before Income Taxes	Income (Loss) Before Income Taxes	459		(2,445)		Income (Loss) Before Income Taxes	702		459
Provision (benefit) for income taxes	Provision (benefit) for income taxes	123		(79)		Provision (benefit) for income taxes	197		123
Net Income (Loss)	Net Income (Loss)	336		(2,366)		Net Income (Loss)	505		336
Less: Net income (loss) attributable to noncontrolling interests	Less: Net income (loss) attributable to noncontrolling interests	84		67		Less: Net income (loss) attributable to noncontrolling interests	88		84
Net Income (Loss) Attributable to Hess Corporation	Net Income (Loss) Attributable to Hess Corporation	$	252	$	(2,433)	Net Income (Loss) Attributable to Hess Corporation	$	417	$	252

Net Income (Loss) Attributable to Hess Corporation Per Common Share:	Net Income (Loss) Attributable to Hess Corporation Per Common Share:					Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	Basic	$	0.82	$	(8.00)	Basic	$	1.35	$	0.82
Diluted	Diluted	$	0.82	$	(8.00)	Diluted	$	1.34	$	0.82
Weighted Average Number of Common Shares Outstanding:	Weighted Average Number of Common Shares Outstanding:					Weighted Average Number of Common Shares Outstanding:
Basic	Basic	305.8		304.0		Basic	308.9		305.8
Diluted	Diluted	307.8		304.0		Diluted	310.4		307.8
Common Stock Dividends Per Share	Common Stock Dividends Per Share	$	0.25	$	0.25	Common Stock Dividends Per Share	$	0.375	$	0.250

See accompanying Notes to Consolidated Financial Statements.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)


		Three Months Ended March 31,
		2021		2020			Three Months Ended March 31,
							2022		2021
		(In millions)
							(In millions)
Net Income (Loss)	Net Income (Loss)	$	336	$	(2,366)	Net Income (Loss)	$	505	$	336
Other Comprehensive Income (Loss):	Other Comprehensive Income (Loss):					Other Comprehensive Income (Loss):
Derivatives designated as cash flow hedges	Derivatives designated as cash flow hedges					Derivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to income	Effect of hedge (gains) losses reclassified to income	51		(64)		Effect of hedge (gains) losses reclassified to income	92		51
Income taxes on effect of hedge (gains) losses reclassified to income	Income taxes on effect of hedge (gains) losses reclassified to income	0		0		Income taxes on effect of hedge (gains) losses reclassified to income	—		—
Net effect of hedge (gains) losses reclassified to income	Net effect of hedge (gains) losses reclassified to income	51		(64)		Net effect of hedge (gains) losses reclassified to income	92		51
Change in fair value of cash flow hedges	Change in fair value of cash flow hedges	(102)		990		Change in fair value of cash flow hedges	(455)		(102)
Income taxes on change in fair value of cash flow hedges	Income taxes on change in fair value of cash flow hedges	0		0		Income taxes on change in fair value of cash flow hedges	—		—
Net change in fair value of cash flow hedges	Net change in fair value of cash flow hedges	(102)		990		Net change in fair value of cash flow hedges	(455)		(102)
Change in derivatives designated as cash flow hedges, after taxes	Change in derivatives designated as cash flow hedges, after taxes	(51)		926		Change in derivatives designated as cash flow hedges, after taxes	(363)		(51)
Pension and other postretirement plans	Pension and other postretirement plans					Pension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses	(Increase) reduction in unrecognized actuarial losses	14		0		(Increase) reduction in unrecognized actuarial losses	—		14
Income taxes on actuarial changes in plan liabilities	Income taxes on actuarial changes in plan liabilities	0		0		Income taxes on actuarial changes in plan liabilities	—		—
(Increase) reduction in unrecognized actuarial losses, net	(Increase) reduction in unrecognized actuarial losses, net	14		0		(Increase) reduction in unrecognized actuarial losses, net	—		14
Amortization of net actuarial losses	Amortization of net actuarial losses	16		12		Amortization of net actuarial losses	3		16
Income taxes on amortization of net actuarial losses	Income taxes on amortization of net actuarial losses	0		0		Income taxes on amortization of net actuarial losses	—		—
Net effect of amortization of net actuarial losses	Net effect of amortization of net actuarial losses	16		12		Net effect of amortization of net actuarial losses	3		16
Change in pension and other postretirement plans, after taxes	Change in pension and other postretirement plans, after taxes	30		12		Change in pension and other postretirement plans, after taxes	3		30
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss)	(21)		938		Other Comprehensive Income (Loss)	(360)		(21)
Comprehensive Income (Loss)	Comprehensive Income (Loss)	315		(1,428)		Comprehensive Income (Loss)	145		315
Less: Comprehensive income (loss) attributable to noncontrolling interests	Less: Comprehensive income (loss) attributable to noncontrolling interests	84		67		Less: Comprehensive income (loss) attributable to noncontrolling interests	88		84
Comprehensive Income (Loss) Attributable to Hess Corporation	Comprehensive Income (Loss) Attributable to Hess Corporation	$	231	$	(1,495)	Comprehensive Income (Loss) Attributable to Hess Corporation	$	57	$	231

See accompanying Notes to Consolidated Financial Statements.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED CASH FLOWS (UNAUDITED)


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Cash Flows From Operating Activities	Cash Flows From Operating Activities					Cash Flows From Operating Activities
Net income (loss)	Net income (loss)	$	336	$	(2,366)	Net income (loss)	$	505	$	336
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:	Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:					Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Gains) on asset sales, net						(Gains) on asset sales, net	(22)		—
Depreciation, depletion and amortization						Depreciation, depletion and amortization	337		396

Depreciation, depletion and amortization		396		561
Impairment		0		2,126
Exploratory dry hole costs		0		135

Exploration lease and other impairment	Exploration lease and other impairment	4		32		Exploration lease and other impairment	6		4
Pension settlement loss	Pension settlement loss	1		0		Pension settlement loss	—		1
Stock compensation expense	Stock compensation expense	25		29		Stock compensation expense	33		25
Noncash (gains) losses on commodity derivatives, net	Noncash (gains) losses on commodity derivatives, net	24		70		Noncash (gains) losses on commodity derivatives, net	55		24
Provision (benefit) for deferred income taxes and other tax accruals	Provision (benefit) for deferred income taxes and other tax accruals	29		(85)		Provision (benefit) for deferred income taxes and other tax accruals	38		29
Changes in operating assets and liabilities:	Changes in operating assets and liabilities:					Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(Increase) decrease in accounts receivable	(329)		258		(Increase) decrease in accounts receivable	(642)		(329)
(Increase) decrease in inventories	(Increase) decrease in inventories	159		31		(Increase) decrease in inventories	(20)		159
Increase (decrease) in accounts payable and accrued liabilities	Increase (decrease) in accounts payable and accrued liabilities	(127)		(263)		Increase (decrease) in accounts payable and accrued liabilities	81		(127)
Increase (decrease) in taxes payable	Increase (decrease) in taxes payable	87		(63)		Increase (decrease) in taxes payable	(399)		87
Changes in other operating assets and liabilities	Changes in other operating assets and liabilities	(14)		(20)		Changes in other operating assets and liabilities	(128)		(14)
Net cash provided by (used in) operating activities	Net cash provided by (used in) operating activities	591		445		Net cash provided by (used in) operating activities	(156)		591
Cash Flows From Investing Activities	Cash Flows From Investing Activities					Cash Flows From Investing Activities
Additions to property, plant and equipment - E&P	Additions to property, plant and equipment - E&P	(358)		(740)		Additions to property, plant and equipment - E&P	(491)		(358)
Additions to property, plant and equipment - Midstream	Additions to property, plant and equipment - Midstream	(27)		(78)		Additions to property, plant and equipment - Midstream	(55)		(27)

Proceeds from asset sales, net of cash sold						Proceeds from asset sales, net of cash sold	24		—

Net cash provided by (used in) investing activities	Net cash provided by (used in) investing activities	(385)		(818)		Net cash provided by (used in) investing activities	(522)		(385)
Cash Flows From Financing Activities	Cash Flows From Financing Activities					Cash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or less	Net borrowings (repayments) of debt with maturities of 90 days or less	(10)		60		Net borrowings (repayments) of debt with maturities of 90 days or less	1		(10)
Debt with maturities of greater than 90 days:	Debt with maturities of greater than 90 days:					Debt with maturities of greater than 90 days:
Borrowings	Borrowings	0		1,000		Borrowings	—		—
Repayments	Repayments	(3)		0		Repayments	(505)		(3)
Proceeds from sale of Class A shares of Hess Midstream LP	Proceeds from sale of Class A shares of Hess Midstream LP	70		0		Proceeds from sale of Class A shares of Hess Midstream LP	—		70
Payments on finance lease obligations	Payments on finance lease obligations	(2)		(1)		Payments on finance lease obligations	(2)		(2)

Cash dividends paid	Cash dividends paid	(80)		(81)		Cash dividends paid	(119)		(80)
Employee stock options exercised						Employee stock options exercised	33		12
Noncontrolling interests, net	Noncontrolling interests, net	(67)		(63)		Noncontrolling interests, net	(74)		(67)
Other, net	Other, net	13		(7)		Other, net	1		1
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(79)		908		Net cash provided by (used in) financing activities	(665)		(79)
Net Increase (Decrease) in Cash and Cash Equivalents	Net Increase (Decrease) in Cash and Cash Equivalents	127		535		Net Increase (Decrease) in Cash and Cash Equivalents	(1,343)		127
Cash and Cash Equivalents at Beginning of Year	Cash and Cash Equivalents at Beginning of Year	1,739		1,545		Cash and Cash Equivalents at Beginning of Year	2,713		1,739
Cash and Cash Equivalents at End of Period	Cash and Cash Equivalents at End of Period	$	1,866	$	2,080	Cash and Cash Equivalents at End of Period	$	1,370	$	1,866

See accompanying Notes to Consolidated Financial Statements.

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			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, 2022																	For the Three Months Ended March 31, 2022
Balance at January 1, 2022																	Balance at January 1, 2022	$	310	$	6,017	$	379	$	(406)	$	6,300	$	726	$	7,026
Net income (loss)																	Net income (loss)	—		—		417		—		417		88		505
Other comprehensive income (loss)																	Other comprehensive income (loss)	—		—		—		(360)		(360)		—		(360)
Share-based compensation																	Share-based compensation	1		66		—		—		67		—		67
Dividends on common stock																	Dividends on common stock	—		—		(116)		—		(116)		—		(116)
Noncontrolling interests, net																	Noncontrolling interests, net	—		—		—		—		—		(74)		(74)
Balance at March 31, 2022																	Balance at March 31, 2022	$	311	$	6,083	$	680	$	(766)	$	6,308	$	740	$	7,048
For the Three Months Ended March 31, 2021	For the Three Months Ended March 31, 2021																For the Three Months Ended March 31, 2021
Balance at January 1, 2021	Balance at January 1, 2021		$	307	$	5,684	$	130	$	(755)	$	5,366	$	969	$	6,335	Balance at January 1, 2021	$	307	$	5,684	$	130	$	(755)	5,366		$	969	$	6,335
Net income (loss)	Net income (loss)		—		—		252		—		252		84		336		Net income (loss)	—		—		252		—		252		84		336
Other comprehensive income (loss)	Other comprehensive income (loss)		—		—		—		(21)		(21)		—		(21)		Other comprehensive income (loss)	—		—		—		(21)		(21)		—		(21)
Share-based compensation	Share-based compensation		1		39		—		—		40		—		40		Share-based compensation	1		39		—		—		40		—		40
Dividends on common stock	Dividends on common stock		—		—		(77)		—		(77)		—		(77)		Dividends on common stock	—		—		(77)		—		(77)		—		(77)
Sale of Class A shares of Hess Midstream LP	Sale of Class A shares of Hess Midstream LP		—		56		—		—		56		41		97		Sale of Class A shares of Hess Midstream LP	—		56		—		—		56		41		97
Noncontrolling interests, net	Noncontrolling interests, net		—		—		—		—		—		(67)		(67)		Noncontrolling interests, net	—		—		—		—		—		(67)		(67)
Balance at March 31, 2021	Balance at March 31, 2021		$	308	$	5,779	$	305	$	(776)	$	5,616	$	1,027	$	6,643	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.

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~~2022 and December 31, ~~2020,~~2021, the consolidated results of operations for the three months ended March 31, ~~2021~~2022 and ~~2020,~~2021, and consolidated cash flows for the three months ended March 31, ~~2021~~2022 and ~~2020.~~2021. 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.~~2021.

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 2 chartered very large crude carriers (VLCCs) for sale in Asian markets. The 2 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.~~


	March 31, 2022		December 31, 2021

	(In millions)
Crude oil and natural gas liquids	$	83	$	52
Materials and supplies	160		171
Total Inventories	$	243	$	223

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~~2022 (in millions):


Balance at January 1, ~~2021~~2022	$	~~459~~681
Additions to capitalized exploratory well costs pending the determination of proved reserves	17120
Balance at March 31, ~~2021~~2022	$	~~476~~801

~~Capitalized~~In the first quarter, additions to capitalized exploratory well costs pending determination of proved reserves related to wells drilled on the Stabroek Block (Hess 30%), offshore Guyana and drilling at the Huron prospect (Hess 40%) in the Gulf of Mexico.

At March 31, 2022, exploratory well costs capitalized for greater than one year following completion of drilling ~~were $375~~of $467 million ~~at March 31, 2021 and primarily related to:~~ was comprised of the following:

Guyana: Approximately ~~85%~~90% 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.~~Block. In April 2022, the government of Guyana and the partners sanctioned the development of the Yellowtail Field, the fourth sanctioned project on the block. Approximately $90 million of capitalized exploratory well costs at March 31, 2022 related to the Yellowtail Field will be reclassified to wells, facilities and equipment in the second quarter of 2022. The operator plans further appraisal drilling on the Block and is conducting pre-development planning for additional phases of ~~development beyond the three previously sanctioned development projects on the Block.~~development.

~~PART I - FINANCIAL INFORMATION (CONT’D.)~~

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)~~

Joint Development Area (JDA): Approximately ~~10%~~8% 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 3 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%2% 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 1 successful exploration well. Subsurface evaluation and pre-development studies are ongoing.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

4. Hess Midstream LP

InAt 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 in31, 2022, Hess Midstream LP ~~on a consolidated basis.~~

~~At March 31, 2021 Hess Midstream LP,~~(Hess Midstream), a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling ~~$1,984~~$2,668 million (December 31, ~~2020: $2,026~~2021: $2,694 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~~included cash and cash equivalents totaling $2$3 million (December 31, ~~2020: $3~~2021: $2 million), property, plant and equipment with a carrying value of ~~$3,095~~$3,118 million (December 31, ~~2020: $3,111~~2021: $3,125 million) and an equity-method investment ~~of $104 million (December 31, 2020: $108 million)~~ in the Little Missouri 4 (LM4) gas processing ~~plant.~~plant of $97 million (December 31, 2021: $102 million).

LM4 is a 200 million standard cubic feet per day gas processing plant located south of the Missouri River in McKenzie County, North Dakota, that was constructed as part of a 50/50 joint venture between Hess Midstream and Targa Resources Corp. Hess Midstream has a natural gas processing agreement with LM4 under which it pays a processing fee and reimburses LM4 for its proportionate share of electricity costs. The processing fees included in Operating costs and expenses in the Statement of Consolidated Income for the three months ended March 31, 2022 were $5 million (2021: $7 million).

In March 2021, Hess Midstream completed an underwritten public equity offering of 6.9 million Class A shares held by Hess and Global Infrastructure Partners (GIP). These Class A shares of Hess Midstream were obtained by Hess and GIP through the exchange of 6.9 million of their Class B units of Hess Midstream Operations LP (HESM Opco), a consolidated subsidiary of Hess Midstream. As a result of this transaction, Hess received net proceeds of $70 million and recorded an increase in additional paid-in capital and noncontrolling interests of $56 million and $41 million, respectively. The increase of $41 million in noncontrolling interests is comprised of $14 million resulting from the change in ownership and $27 million due to the recognition of a deferred tax asset as a result of an increase in the tax basis of Hess Midstream's investment in HESM Opco.

5. Accrued Liabilities

Accrued Liabilities consisted of the following:


		March 31, 2021		December 31, 2020			March 31, 2022		December 31, 2021

		(In millions)					(In millions)
Accrued operating and marketing expenditures						Accrued operating and marketing expenditures	$	589	$	462
Accrued capital expenditures	Accrued capital expenditures	$	263	$	345	Accrued capital expenditures	513		479
Accrued operating and marketing expenditures		263		325
Accrued payments to royalty and working interest owners	Accrued payments to royalty and working interest owners	227		170		Accrued payments to royalty and working interest owners	255		253
Liabilities held for sale		138		0
Current portion of asset retirement obligations						Current portion of asset retirement obligations	204		185
Accrued interest on debt	Accrued interest on debt	96		126		Accrued interest on debt	100		138
Accrued compensation and benefits	Accrued compensation and benefits	93		117		Accrued compensation and benefits	70		124
Current portion of asset retirement obligations		156		105
Other accruals	Other accruals	18		63		Other accruals	18		69
Total Accrued Liabilities	Total Accrued Liabilities	$	1,254	$	1,251	Total Accrued Liabilities	$	1,749	$	1,710

6. Debt

In February 2022, we repaid the remaining $500 million outstanding under our $1 billion term loan previously scheduled to mature in March 2023.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

6.7. Revenue

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


		Exploration and Production										Midstream		Eliminations		Total			Exploration and Production										Midstream		Eliminations		Total
		United States		Guyana		Malaysia & JDA		Other (a)		E&P Total									United States		Guyana		Malaysia and JDA		Other (a)		E&P Total

		(In millions)
Three Months Ended March 31, 2022																		Three Months Ended March 31, 2022
Sales of our net production volumes:																		Sales of our net production volumes:
Crude oil revenue																		Crude oil revenue	$	836	$	226	$	31	$	146	$	1,239	$	—	$	—	$	1,239
Natural gas liquids revenue																		Natural gas liquids revenue	181		—		—		—		181		—		—		181
Natural gas revenue																		Natural gas revenue	85		—		190		5		280		—		—		280
Sales of purchased oil and gas																		Sales of purchased oil and gas	660		4		—		35		699		—		—		699
Intercompany revenue																		Intercompany revenue	—		—		—		—		—		312		(312)		—
Total revenues from contracts with customers																		Total revenues from contracts with customers	1,762		230		221		186		2,399		312		(312)		2,399
Other operating revenues (b)																		Other operating revenues (b)	(58)		(15)		—		(13)		(86)		—		—		(86)
Total sales and other operating revenues																		Total sales and other operating revenues	$	1,704	$	215	$	221	$	173	$	2,313	$	312	$	(312)	$	2,313
Three Months Ended March 31, 2021	Three Months Ended March 31, 2021																	Three Months Ended March 31, 2021
Sales of our net production volumes:	Sales of our net production volumes:																	Sales of our net production volumes:
Crude oil revenue	Crude oil revenue	$	885	$	181	$	22	$	116	$	1,204	$	0	$	—	$	1,204	Crude oil revenue	$	885	$	181	$	22	$	116	$	1,204	$	—	$	—	$	1,204
Natural gas liquids revenue	Natural gas liquids revenue	143		0		0		0		143		0		—		143		Natural gas liquids revenue	143		—		—		—		143		—		—		143
Natural gas revenue	Natural gas revenue	113		0		163		3		279		0		—		279		Natural gas revenue	113		—		163		3		279		—		—		279
Sales of purchased oil and gas	Sales of purchased oil and gas	298		4		0		19		321		0		—		321		Sales of purchased oil and gas	298		4		—		19		321		—		—		321
Intercompany revenue	Intercompany revenue	0		0		0		0		0		289		(289)		—		Intercompany revenue	—		—		—		—		—		289		(289)		—
Total revenues from contracts with customers	Total revenues from contracts with customers	1,439		185		185		138		1,947		289		(289)		1,947		Total revenues from contracts with customers	1,439		185		185		138		1,947		289		(289)		1,947
Other operating revenues (b)	Other operating revenues (b)	(41)		(4)		0		(4)		(49)		0		0		(49)		Other operating revenues (b)	(41)		(4)		—		(4)		(49)		—		—		(49)
Total sales and other operating revenues	Total sales and other operating revenues	$	1,398	$	181	$	185	$	134	$	1,898	$	289	$	(289)	$	1,898	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	$	0	$	—	$	732
Natural gas liquids revenue		49		0		0		0		49		0		—		49
Natural gas revenue		38		0		139		4		181		0		—		181
Sales of purchased oil and gas		324		1		0		0		325		0		—		325
Intercompany revenue		0		0		0		0		0		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		0		0		67
Total sales and other operating revenues		$	1,122	$	45	$	142	$	45	$	1,354	$	291	$	(291)	$	1,354

(a)Other includes Libya and our interests in Denmark, ~~and Libya.~~which were sold in the third quarter of 2021.

(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.~~2022. 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. At March 31, 2022, contract liabilities of $24 million (December 31, 2021: $24 million) resulted from a take-or-pay deficiency payment received in the fourth quarter of 2021 that is subject to a make-up period expiring in December 2023. At March 31, 2022 and December 31, 2021, there were no contract assets.

~~7. Impairment~~8. Retirement Plans

Components of net periodic benefit cost consisted of the following:


	Three Months Ended March 31,
	2022		2021

	(In millions)
Service cost	$	13	$	14
Interest cost (a)	16		14
Expected return on plan assets (a)	(53)		(50)
Amortization of unrecognized net actuarial losses (a)	3		15
Settlement loss (a)	—		1
Net periodic benefit cost (income) (a)	$	(21)	$	(6)

(a) Net non-service cost included in Other, net in the Statement of Consolidated Income for the three months ended March 31, 2022 was income of $34 million (2021: income of $20 million).

In ~~the first quarter of 2020,~~2022, we ~~recorded noncash impairment charges totaling $2.1 billion ($2.0 billion after income taxes) related~~expect to contribute approximately $45 million 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.funded pension plans.

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 0
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,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Net income (loss) attributable to Hess Corporation:	Net income (loss) attributable to Hess Corporation:					Net income (loss) attributable to Hess Corporation:
Net income (loss)	Net income (loss)	$	336	$	(2,366)	Net income (loss)	$	505	$	336
Less: Net income (loss) attributable to noncontrolling interests	Less: Net income (loss) attributable to noncontrolling interests	84		67		Less: Net income (loss) attributable to noncontrolling interests	88		84
Net income (loss) attributable to Hess Corporation	Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)	Net income (loss) attributable to Hess Corporation	$	417	$	252
Weighted average number of common shares outstanding:	Weighted average number of common shares outstanding:					Weighted average number of common shares outstanding:
Basic	Basic	305.8		304.0		Basic	308.9		305.8
Effect of dilutive securities	Effect of dilutive securities					Effect of dilutive securities
Restricted common stock	Restricted common stock	0.8		0		Restricted common stock	0.7		0.8
Stock options	Stock options	0.4		0		Stock options	0.6		0.4
Performance share units	Performance share units	0.8		0		Performance share units	0.2		0.8
Diluted	Diluted	307.8		304.0		Diluted	310.4		307.8

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


		Three Months Ended March 31,			Three Months Ended March 31,
		2021	2020		2022	2021
Restricted common stock	Restricted common stock	189,000	2,015,659	Restricted common stock	97	189,000
Stock options	Stock options	1,164,214	4,086,340	Stock options	75,413	1,164,214
Performance share units	Performance share units	36,134	1,296,356	Performance share units	31,352	36,134

During the three months ended March 31, ~~2021,~~2022, we granted ~~695,832~~562,530 shares of restricted stock ~~(2020: 1,117,009)~~(2021: 695,832), ~~319,295 stock options (2020: 686,639), and 205,155~~178,008 performance share units ~~(2020: 307,999)~~(2021: 205,155) and 269,748 stock options (2021: 319,295).

~~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.~~United States (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 32 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.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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~~Environmental Protection Agency (EPA) to study the same contamination; this work remains ongoing. We and other parties settled a cost recovery claim by the State of New Jersey and agreed with the EPA to fund remediation of a portion of the site. ~~On March 4,~~Since 2016, the EPA has issued a Record of Decision (ROD) ~~in respect of~~selecting a dredge and cap remedy for both 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~~and the upper nine miles of the Lower Passaic River orat an estimated cost of approximately $1.82 billion. The ROD does not address 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 final 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

~~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.

Hess Corporation and its subsidiary HONX, Inc. have also been named as defendants in various personal injury claims alleging exposure to asbestos and/or other alleged toxic substances while working at a former refinery (owned and operated by subsidiaries or related entities) located in St. Croix, U.S. Virgin Islands. HONX, Inc. has initiated a Chapter 11 § 524G process to resolve these asbestos-related claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 and working interest payments. We may also be exposed to future decommissioning liabilities for divested assets in the event the current or future owners of facilities previously owned by us are determined to be unable to perform such actions, whether due to bankruptcy or otherwise. 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 2 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 $ 0 $ — $ — $ 1,898
Intersegment Revenues 0 289 — (289) —
Sales and Other Operating Revenues $ 1,898 $ 289 $ — $ (289) $ 1,898
Net Income (Loss) attributable to Hess Corporation $ 308 $ 75 $ (131) $ 0 $ 252
Depreciation, Depletion and Amortization 355 40 1 0 396
Provision (Benefit) for Income Taxes 120 3 0 0 123
Capital Expenditures 280 23 0 0 303
For the Three Months Ended March 31, 2020
Sales and Other Operating Revenues - Third parties $ 1,354 $ 0 $ — $ — $ 1,354
Intersegment Revenues 0 291 — (291) —
Sales and Other Operating Revenues $ 1,354 $ 291 $ — $ (291) $ 1,354
Net Income (Loss) attributable to Hess Corporation $ (2,371) $ 61 $ (123) $ 0 $ (2,433)
Depreciation, Depletion and Amortization 521 38 2 0 561
Impairment 2,126 0 0 0 2,126
Provision (Benefit) for Income Taxes (77) 2 (4) 0 (79)
Capital Expenditures 609 57 0 0 666


	Exploration and Production		Midstream		Corporate, Interest and Other		Eliminations		Total

	(In millions)
For the Three Months Ended March 31, 2022
Sales and Other Operating Revenues - Third parties	$	2,313	$	—	$	—	$	—	$	2,313
Intersegment Revenues	—		312		—		(312)		—
Sales and Other Operating Revenues	$	2,313	$	312	$	—	$	(312)	$	2,313

Net Income (Loss) attributable to Hess Corporation	$	460	$	72	$	(115)	$	—	$	417
Depreciation, Depletion and Amortization	292		45		—		—		337
Provision (Benefit) for Income Taxes	192		5		—		—		197
Capital Expenditures	543		37		—		—		580
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

Identifiable assets by operating segment were as follows:


	March 31, 2022		December 31, 2021

	(In millions)
Exploration and Production	$	14,403	$	14,173
Midstream	3,651		3,671
Corporate, Interest and Other	1,744		2,671
Total	$	19,798	$	20,515

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.~~gas, as well as changes in interest rates and foreign currency values. Financial risk management activities include transactions designed to reduce risk in the selling prices of crude oil or natural gas we produce or by reducing our exposure to foreign currency or interest rate movements. Generally, futures, swaps or option strategies may be used to fix the forward selling price, or establish a floor price or a range banded with a floor and ceiling 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 or swaps 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,~~2022, these ~~forward contracts~~instruments 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			March 31, 2022		December 31, 2021

		(In millions)					(In millions)
Commodity - crude oil put options (millions of barrels)		41.3		27.4
Commodity - crude oil hedge contracts (millions of barrels)						Commodity - crude oil hedge contracts (millions of barrels)	41.3		54.8

Foreign exchange forwards	Foreign exchange forwards	$	121	$	163	Foreign exchange forwards	$	156	$	145
Interest rate swaps	Interest rate swaps	$	100	$	100	Interest rate swaps	$	100	$	100

~~As of March~~At December 31, 2021, we ~~have purchased West Texas Intermediate (WTI) put options of 120,000~~had hedged 90,000 barrels of oil per day (bopd) with ~~an average monthly floor price of $55 per barrel and Brent put options of 30,000 bopd~~WTI collars with an average monthly floor price of $60 per barrel and an average monthly ceiling price of $100 per barrel and 60,000 bopd with Brent collars with an average monthly floor price of $65 per barrel and an average monthly ceiling price of $105 per barrel for calendar 2022. In the first quarter of 2022, we purchased WTI and Brent call options to remove the ceiling price on our price collars for the ~~remainder~~period April 1, 2022 through December 31, 2022 for $325 million. As a result, during this period, we are able to realize average monthly WTI and Brent selling prices above $100 per barrel and $105 per barrel, respectively, to the extent that market prices at the time exceed these thresholds. The WTI $60 per barrel put options and the Brent $65 per barrel put options that established the floor price in our collars remain outstanding for 90,000 bopd and 60,000 bopd, respectively, through December 31, 2022.

The table below reflects the fair values of ~~2021.~~risk management derivative instruments.


	Assets		Liabilities

	(In millions)
March 31, 2022
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	64	$	—
Interest rate swaps	—		(2)
Total derivative contracts designated as hedging instruments	64		(2)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards and swaps	—		—
Total derivative contracts not designated as hedging instruments	—		—
Gross fair value of derivative contracts	64		(2)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	64	$	(2)
December 31, 2021
Derivative Contracts Designated as Hedging Instruments:
Crude oil collars	$	155	$	—
Interest rate swaps	2		—
Total derivative contracts designated as hedging instruments	157		—
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards and swaps	—		(1)
Total derivative contracts not designated as hedging instruments	—		(1)
Gross fair value of derivative contracts	157		(1)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	157	$	(1)

At March 31, 2022 and December 31, 2021, the fair value of our crude oil hedge contracts is presented within Other current assets and the fair value of our foreign exchange forwards and swaps is presented within Accrued liabilities in our Consolidated

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 $ 0
Interest rate swaps 4 0
Total derivative contracts designated as hedging instruments 158 0
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards 0 (2)
Total derivative contracts not designated as hedging instruments 0 (2)
Gross fair value of derivative contracts 158 (2)
Gross amounts offset in the Consolidated Balance Sheet 0 0
Net Amounts Presented in the Consolidated Balance Sheet $ 158 $ (2)
December 31, 2020
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options $ 64 $ 0
Crude oil swaps 0 (54)
Interest rate swaps 5 0
Total derivative contracts designated as hedging instruments 69 (54)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards 0 (1)
Total derivative contracts not designated as hedging instruments 0 (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 2 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~~ Balance Sheet.~~Other current assets~~ ~~and~~ ~~Accrued liabilities, respectively, in our~~ ~~Consolidated Balance Sheet~~. The fair value of our interest rate swaps is presented within Other liabilities and deferred credits at March 31, 2022 and within Other assets ~~in our~~ ~~Consolidated Balance Sheet. The fair value of our foreign exchange forwards is presented within~~ ~~Accrued liabilities~~at December 31, 2021 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:~~ derivatives designated as cash flow hedges: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~~$92 million in the ~~first quarter of 2020.~~three months ended March 31, 2022 (2021 Q1: decreased by $51 million). At March 31, ~~2021,~~2022, pre-tax deferred losses in Accumulated other comprehensive income (loss)related to outstanding crude oil ~~price~~ hedging contracts were ~~$47~~$433 million ($433 million after income taxes), all of which will be reclassified into earnings during the remainder of ~~2021~~2022 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~~We had interest rate swaps with gross notional amounts totaling $100 million ~~which were designated as fair value hedges~~at March 31, 2022 and ~~relate to debt where we have converted~~December 31, 2021, that convert 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,~~2022, the change in fair value of interest rate swaps was a decrease ~~in the asset~~of $4 million (2021 Q1: decrease 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~~nil in the three months ended March 31, ~~2021 (2020~~2022 (2021 Q1: losses of $1 ~~million loss)~~million). 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~~gains of $1$4 million in the three months ended March 31, ~~2021 (2020~~2022 (2021 Q1: ~~$2 million gain)~~losses of $1 million).

~~PART I - FINANCIAL INFORMATION (CONT’D.)~~

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)~~

Fair Value Measurement:

At March 31, ~~2021,~~2022, our total long-term debt, which was substantially comprised of ~~fixed rate~~fixed-rate debt instruments, had a carrying value of ~~$8,286~~$7,956 million and a fair value of ~~$9,381~~$8,801 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~~2022 and December 31, ~~2020.~~ 2021.

13. Subsequent Events

OnIn April ~~30, 2021, we completed the sale~~2022, Hess Corporation received total proceeds of ~~our previously announced Little Knife and Murphy Creek nonstrategic acreage interests in the Bakken for total consideration of $312~~$346 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~~related to 2 Hess Midstream ~~LP infrastructure. Net production~~equity transactions. During the month, Hess Midstream completed a public offering of approximately 10.2 million Hess Midstream Class A shares held by Hess Corporation and GIP. We received net proceeds of $146 million from the ~~acreage during~~public offering. Concurrent with the ~~first quarter~~public offering, HESM Opco repurchased approximately 13.6 million HESM Opco Class B units from Hess Corporation and GIP for $400 million, of ~~2021~~which we received net proceeds of $200 million. The purchase was financed by HESM Opco's issuance of $400 million of 5.500% senior unsecured notes due 2030. As a result of these transactions, our ownership in Hess Midstream, on a consolidated basis, decreased from 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~~43.5% at March 31, 2022 to ~~May 2024 and incorporating customary provisions for the eventual replacement of the London Interbank Offered Rate (LIBOR)~~approximately 41.0%.

1514

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~~2022 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.~~2021. 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.~~2021.

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.)~~U.S., Guyana, the Malaysia/Thailand Joint Development Area (JDA), ~~Malaysia,~~ and ~~Denmark.~~Malaysia. 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 and our partners have ~~announced eighteen~~discovered a significant ~~discoveries.~~resource base and are executing a multi-phased development of the Block. The Liza Phase 1 development, ~~achieved first production in December 2019, and has a nameplate~~with production capacity of approximately 120,000 gross bopd, completed production optimization work in April that expanded its production capacity to more than 140,000 bopd. The Liza Phase 2 development ~~was sanctioned in the second quarter of 2019 and remains on track to achieve~~achieved first production ~~by early~~in February 2022 ~~with~~and is expected to reach its production capacity of approximately 220,000 gross ~~bopd.~~bopd by the third quarter. A third development, Payara, was sanctioned in the third quarter of 2020 and is expected to achieve first production in ~~2024,~~late 2023 with production capacity of approximately 220,000 gross bopd. ~~The discovered resources to date on the Stabroek Block are~~A fourth development, Yellowtail, was sanctioned in April 2022 and is expected to ~~underpin up~~achieve first production in 2025, with production capacity of approximately 250,000 gross bopd. We currently plan to ~~ten~~have six floating production, storage and offloading vessels ~~(FPSOs)~~(FPSO) with an aggregate expected production capacity of more than 1 million gross bopd on the ~~first six~~Stabroek Block in 2027, and the potential for up to ten FPSOs ~~expected by 2027.~~to develop the current discovered recoverable resource base.

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,~~

In April 2022, Hess Corporation received total proceeds of $346 million related to two Hess Midstream LP inequity transactions. During the ~~Notes to Consolidated Financial Statements~~.

month, Hess ~~Response to Global Pandemic~~

~~COVID-19 continues to have~~Midstream completed a ~~profound impact on society~~public offering of approximately 10.2 million Hess Midstream Class A shares held by Hess Corporation 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~~GIP. We received net proceeds of ~~$70~~$146 million ~~for~~from the public offering. Concurrent with the public offering, HESM Opco repurchased approximately 13.6 million HESM Opco Class B units from Hess Corporation and GIP for $400 million, of ~~3,450,000 Class A shares~~which we received net proceeds of $200 million. The purchase was financed by HESM Opco's issuance of $400 million of 5.500% senior unsecured notes due 2030. As a result of these transactions, our ownership in Hess Midstream, ~~LP. In~~on a consolidated basis, decreased from approximately 43.5% at March ~~2021,~~31, 2022, to approximately 41.0%.

First Quarter Highlights and 2022 Outlook

Following the startup of the Liza Phase 2 project in February 2022, we ~~entered into an agreement to sell~~repaid the remaining $500 million outstanding under our ~~interests~~$1 billion term loan, and 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,March 2022, we ~~completed the sale of~~announced a 50% increase in 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.dividend on common stock. Excluding our Midstream segment, we ended the first quarter of ~~2021~~2022 with approximately ~~$1.86~~$1.37 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,~~

Oil and ~~cash and cash equivalents~~gas net production in 2022, excluding Libya, is forecast to be at ~~March 31, 2021 will be sufficient to fund our capital investment program and dividends. We may take any~~the low end of the ~~following steps,~~range of 325,000 barrels of oil equivalent per day (boepd) to 330,000 boepd reflecting our initial assessment of the impact from severe weather in North Dakota in April. For the remainder of 2022, we have WTI put options for 90,000 bopd with an average monthly floor price of $60 per barrel and Brent put options for 60,000 bopd with an average monthly floor price of $65 per barrel.

Our E&P capital and exploratory expenditures guidance for 2022 is approximately $2.6 billion. We are considering adding a fourth rig in the Bakken in the second half of this year which could add up to $100 million to our 2022 capital spend, and we also expect industry cost inflation to potentially increase capital spend by $80 million to $100 million for this year, including higher drilling and completion costs in the Bakken that we now expect to average approximately $6.2 million per well, or ~~a combination thereof,~~7% above last year.

First Quarter Results

In the first quarter of 2022, net income was $417 million, compared with net income of $252 million in the first quarter of 2021. Excluding items affecting comparability of earnings between periods detailed on page 23, adjusted net income was $404 million in the first quarter of 2022. The improvement in first quarter 2022 adjusted after-tax earnings compared to ~~improve our liquidity and financial position: reduce~~ the ~~planned capital program and other cash outlays, including dividends, pursue asset~~prior-year quarter primarily reflects higher realized selling prices, partially offset by lower sales ~~borrow against our committed revolving credit facility, or issue debt or equity securities.~~volumes.

1615

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,~~2022, E&P had net income of ~~$308~~$460 million compared with a net ~~loss~~income of ~~$2,371~~$308 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.~~2021. Total net production, excluding Libya, averaged 276,000 boepd in the first quarter 2022, compared with 315,000 boepd in the first quarter of 2021, ~~compared with 344,000 boepd in the first quarter of 2020~~ or ~~332,000~~304,000 boepd pro forma for ~~the sale of our interest in the Shenzi Field.~~assets sold. The average realized crude oil selling price, including hedging, was $86.75 per barrel in the first quarter of 2022, compared with $50.02 per barrel in the first quarter of ~~2021, compared with $45.94 per barrel in the first quarter of 2020.~~2021. The average realized NGL selling price in the first quarter of ~~2021~~2022 was ~~$29.49~~$39.79 per barrel, compared with ~~$9.32~~$29.49 per barrel in the prior-year quarter, while the average realized natural gas selling price was ~~$4.90~~$5.28 per thousand cubic feet (mcf) in the first quarter of ~~2021,~~2022, compared with ~~$3.16~~$4.90 per mcf in the first quarter of ~~2020.~~2021.

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

•In North Dakota, net production from the Bakken ~~oil shale play~~ averaged ~~158,000~~152,000 boepd for the first quarter of ~~2021 (2020~~2022 (2021 Q1: ~~190,000~~158,000 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~~. Our former Little Knife and Murphy Creek nonstrategic acreage interests that were sold in the ~~Bakken for total consideration~~second quarter 2021 contributed net production of ~~$312 million with an effective date of March 1, 2021. The sale included~~ approximately ~~78,700 net acres, which are located~~5,000 boepd in the ~~southernmost portion~~first quarter of ~~the Corporation's Bakken position~~2021. We operated three rigs, drilled 19 wells, completed 16 wells, and ~~are not connected to Hess Midstream LP infrastructure. Net production from the acreage~~brought 13 new wells online during the first quarter of ~~2021 was approximately 4,500 boepd.~~2022. We forecast net production to be in the range of 140,000 boepd and 145,000 boepd for the second quarter of 2022 and at the low end of the range of 160,000 boepd and 165,000 boepd for the full year 2022 reflecting our initial assessment of the impact from severe weather in April.

•In the Gulf of Mexico, net production for the first quarter of ~~2021~~2022 averaged ~~56,000~~30,000 boepd ~~(2020~~(2021 Q1: ~~74,000~~56,000 boepd), primarily reflecting field decline and unplanned downtime at the ~~sale of our interest~~Baldpate, Penn State, and Llano fields. In February, we spud an exploration well at the Huron prospect (Hess 40%) located at Green Canyon Block 69. Well results are anticipated 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.~~second quarter.

•At the Stabroek Block (Hess 30%), offshore Guyana, net production ~~from the Liza Phase 1 development averaged 31,000~~totaled 30,000 bopd for the first quarter of ~~2021 (2020~~2022 (2021 Q1: ~~15,000~~31,000 bopd). In February 2022, production commenced from the Liza Unity FPSO and contributed 7,000 net bopd in the first quarter of 2022.

The Liza Destiny FPSO, ~~reached~~recently completed production optimization work initiated in March 2022 that expanded its ~~nameplate~~production capacity ofto more than 140,000 gross bopd, from 120,000 gross bopd previously. It is expected to reach its full capacity of more than 140,000 bopd in ~~December 2020 and remained at this level during~~the second quarter. The Liza Unity FPSO is expected to reach its production capacity of approximately 220,000 gross bopd by the third quarter. In the first quarter we sold approximately 2.3 million barrels of ~~2021. In mid-April, production~~oil from ~~the Liza Destiny FPSO was curtailed for several days after a leak was detected~~Guyana and expect to have 7 one-million barrel liftings in the ~~flash gas compressor discharge silencer. Production has since ramped back up~~second quarter and ~~is expected to remain~~8 one-million barrel liftings in both 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 thethird and fourth ~~quarter of 2021.~~quarters.

~~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~~The project is progressing ahead of schedule with first production now expected in ~~2024. A fourth~~late 2023. In April 2022, we announced the final investment decision was made to proceed with 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~~Field on the Stabroek Block ~~are~~after the development plan received approval from the government of Guyana. Yellowtail, the largest development thus far on the Block, will utilize the ONE GUYANA FPSO, which is expected to ~~underpin~~have a production capacity of up to ~~ten FPSOs~~250,000 gross bopd with ~~the~~ first ~~six FPSOs~~production expected ~~by 2027.~~

~~PART I - FINANCIAL INFORMATION (CONT'D.)~~

~~Overview (continued)~~in 2025. Six drill centers are planned with up to 26 production wells and 25 injection wells.

In April, ~~2021,~~ we announced ~~a discovery~~discoveries at ~~the Uaru-2~~Barreleye, Lukanani, and Patwa. The Barreleye-1 well ~~which~~ encountered approximately ~~120~~230 feet of hydrocarbon bearing sandstone reservoirs of which approximately 52 feet is high quality oil ~~bearing sandstone reservoir, including newly identified intervals below the original Uaru-1 discovery.~~bearing. The well was drilled in ~~5,659~~3,840 feet of water and is located approximately ~~6.8~~20 miles ~~south~~southeast of the ~~Uaru-1 well.~~

Liza Field. The ~~Stena DrillMax~~Lukanani-1 well encountered 115 feet of hydrocarbon bearing sandstone reservoirs of which approximately 76 feet is ~~currently appraising~~high quality oil bearing. The well was drilled in water depth of 4,068 feet and is located in the ~~Longtail discovery, which will include a planned sidetrack.~~southeastern part of the Block, approximately 2 miles west of the Pluma discovery. The ~~Noble Don Taylor will drill~~Patwa-1 well encountered 108 feet of hydrocarbon bearing sandstone reservoirs. The well was drilled in 6,315 feet of water and is located approximately 3 miles northwest of 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.Cataback-1 discovery.

•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged ~~37,000~~38,000 boepd for the first quarter of ~~2021 (2020~~2022 (2021 Q1: ~~32,000~~37,000 boepd), including contribution from unitized acreage in Malaysia, while net production from North Malay Basin, offshore Peninsular Malaysia, averaged ~~27,000~~26,000 boepd for the first quarter of ~~2021 (2020~~2022 (2021 Q1: ~~26,000~~27,000 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.

PART I - FINANCIAL INFORMATION (CONT'D.)

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)

~~PART I - FINANCIAL INFORMATION (CONT'D.)~~

~~Consolidated Results of Operations (continued)~~


	Three Months Ended March 31,
	2022		2021

	(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation:
Exploration and Production	$	460	$	308
Midstream	72		75
Corporate, Interest and Other	(115)		(131)
Total	$	417	$	252
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Basic	$	1.35	$	0.82
Diluted	$	1.34	$	0.82

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,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Items Affecting Comparability of Earnings Between Periods, After-Tax:	Items Affecting Comparability of Earnings Between Periods, After-Tax:					Items Affecting Comparability of Earnings Between Periods, After-Tax:
Exploration and Production	Exploration and Production	$	—	$	(2,251)	Exploration and Production	$	—	$	—
Midstream	Midstream	—		—		Midstream	—		—
Corporate, Interest and Other	Corporate, Interest and Other	—		—		Corporate, Interest and Other	13		—
Total	Total	$	—	$	(2,251)	Total	$	13	$	—

The items in the table above are explained on page ~~24.~~23.

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,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Adjusted Net Income (Loss) Attributable to Hess Corporation:	Adjusted Net Income (Loss) Attributable to Hess Corporation:					Adjusted Net Income (Loss) Attributable to Hess Corporation:
Net income (loss) attributable to Hess Corporation	Net income (loss) attributable to Hess Corporation	$	252	$	(2,433)	Net income (loss) attributable to Hess Corporation	$	417	$	252
Less: Total items affecting comparability of earnings between periods, after-tax	Less: Total items affecting comparability of earnings between periods, after-tax	—		(2,251)		Less: Total items affecting comparability of earnings between periods, after-tax	13		—
Adjusted Net Income (Loss) Attributable to Hess Corporation	Adjusted Net Income (Loss) Attributable to Hess Corporation	$	252	$	(182)	Adjusted Net Income (Loss) Attributable to Hess Corporation	$	404	$	252

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


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Net cash provided by operating activities before changes in operating assets and liabilities:	Net cash provided by operating activities before changes in operating assets and liabilities:					Net cash provided by operating activities before changes in operating assets and liabilities:
Net cash provided by (used in) operating activities	Net cash provided by (used in) operating activities	$	591	$	445	Net cash provided by (used in) operating activities	$	(156)	$	591
Changes in operating assets and liabilities	Changes in operating assets and liabilities	224		57		Changes in operating assets and liabilities	1,108		224
Net cash provided by (used in) operating activities before changes in operating assets and liabilities	Net cash provided by (used in) operating activities before changes in operating assets and liabilities	$	815	$	502	Net cash provided by (used in) operating activities before changes in operating assets and liabilities	$	952	$	815

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

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.~~23. 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.

~~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,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Revenues and Non-Operating Income	Revenues and Non-Operating Income					Revenues and Non-Operating Income
Sales and other operating revenues	Sales and other operating revenues	$	1,898	$	1,354	Sales and other operating revenues	$	2,313	$	1,898

Other, net	Other, net	16		8		Other, net	33		16
Total revenues and non-operating income	Total revenues and non-operating income	1,914		1,362		Total revenues and non-operating income	2,346		1,914
Costs and Expenses	Costs and Expenses					Costs and Expenses
Marketing, including purchased oil and gas	Marketing, including purchased oil and gas	542		425		Marketing, including purchased oil and gas	703		542
Operating costs and expenses	Operating costs and expenses	208		214		Operating costs and expenses	251		208
Production and severance taxes	Production and severance taxes	37		42		Production and severance taxes	61		37
Midstream tariffs	Midstream tariffs	262		241		Midstream tariffs	287		262
Exploration expenses, including dry holes and lease impairment	Exploration expenses, including dry holes and lease impairment	33		189		Exploration expenses, including dry holes and lease impairment	43		33
General and administrative expenses	General and administrative expenses	49		52		General and administrative expenses	57		49
Depreciation, depletion and amortization	Depreciation, depletion and amortization	355		521		Depreciation, depletion and amortization	292		355
Impairment		—		2,126

Total costs and expenses	Total costs and expenses	1,486		3,810		Total costs and expenses	1,694		1,486
Results of Operations Before Income Taxes	Results of Operations Before Income Taxes	428		(2,448)		Results of Operations Before Income Taxes	652		428
Provision (benefit) for income taxes	Provision (benefit) for income taxes	120		(77)		Provision (benefit) for income taxes	192		120
Net Income (Loss) Attributable to Hess Corporation	Net Income (Loss) Attributable to Hess Corporation	$	308	$	(2,371)	Net Income (Loss) Attributable to Hess Corporation	$	460	$	308

~~Excluding the E&P items affecting comparability of earnings between periods detailed on page 24, the~~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.

2018

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Selling Prices: Higher realized selling prices in the first quarter of ~~2021,~~2022, increased after-tax ~~results~~earnings by approximately ~~$270~~$430 million compared to the same period in ~~2020.~~2021. Average selling prices were as follows:


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

Average Selling Prices (a)	Average Selling Prices (a)					Average Selling Prices (a)
Crude Oil – Per Barrel (Including Hedging)	Crude Oil – Per Barrel (Including Hedging)					Crude Oil – Per Barrel (Including Hedging)
United States	United States					United States
North Dakota (b)	North Dakota (b)	$	44.97	$	44.05	North Dakota (b)	$	84.77	$	44.97
Offshore	Offshore	53.03		49.33		Offshore	85.17		53.03
Total United States	Total United States	46.73		45.63		Total United States	84.85		46.73
Guyana	Guyana	60.37		43.26		Guyana	90.90		60.37
Malaysia and JDA	Malaysia and JDA	63.27		51.24		Malaysia and JDA	89.27		63.27
Other (c)	Other (c)	57.66		55.60		Other (c)	90.91		57.66
Worldwide	Worldwide	50.02		45.94		Worldwide	86.75		50.02
Crude Oil – Per Barrel (Excluding Hedging)	Crude Oil – Per Barrel (Excluding Hedging)					Crude Oil – Per Barrel (Excluding Hedging)
United States	United States					United States
North Dakota (b)	North Dakota (b)	$	47.62	$	40.54	North Dakota (b)	$	91.55	$	47.62
Offshore	Offshore	56.53		45.65		Offshore	91.52		56.53
Total United States	Total United States	49.56		42.07		Total United States	91.54		49.56
Guyana	Guyana	61.85		36.79		Guyana	99.76		61.85
Malaysia and JDA	Malaysia and JDA	63.27		51.24		Malaysia and JDA	89.27		63.27
Other (c)	Other (c)	59.61		49.14		Other (c)	101.04		59.61
Worldwide	Worldwide	52.52		42.08		Worldwide	94.04		52.52
Natural Gas Liquids – Per Barrel	Natural Gas Liquids – Per Barrel					Natural Gas Liquids – Per Barrel
United States	United States					United States
North Dakota	North Dakota	$	30.32	$	9.31	North Dakota	$	39.88	$	30.32
Offshore	Offshore	21.25		9.39		Offshore	37.48		21.25
Worldwide	Worldwide	29.49		9.32		Worldwide	39.79		29.49
Natural Gas – Per Mcf	Natural Gas – Per Mcf					Natural Gas – Per Mcf
United States	United States					United States
North Dakota	North Dakota	$	5.93	$	1.28	North Dakota	$	4.32	$	5.93
Offshore	Offshore	2.95		1.32		Offshore	4.46		2.95
Total United States	Total United States	4.78		1.30		Total United States	4.35		4.78
Malaysia and JDA	Malaysia and JDA	5.04		4.71		Malaysia and JDA	5.81		5.04
Other (c)	Other (c)	2.69		4.26		Other (c)	4.79		2.69
Worldwide	Worldwide	4.90		3.16		Worldwide	5.28		4.90

(a)Selling prices in the United States and Guyana are adjusted for certain processing and distribution fees included in Marketing expenses. Excluding these fees worldwide selling prices for the first quarter of ~~2021~~2022 would be ~~$56.54 (2020 Q1: $49.44)~~$91.18 (Q1 2021: $56.54) per barrel for crude oil (including hedging), ~~$59.04 (2020 Q1: $45.58)~~$98.47 (Q1 2021: $59.04) per barrel for crude oil (excluding hedging), ~~$29.73 (2020 Q1: $9.52)~~$39.98 (Q1 2021: $29.73) per barrel for NGLs and ~~$5.02 (2020 Q1: $3.26)~~$5.39 (Q1 2021: $5.02) 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 Libya and our former interests in Denmark, ~~and Libya.~~which were sold in the third quarter of 2021.

Crude oil hedging activities were a net loss of $92 million before and after income taxes in the first quarter of 2022, and a net loss of $51 million before and after income taxes in the first quarter of ~~2021, and a net gain~~2021. For the remainder of ~~$64 million before and after income taxes in the first quarter of 2020.~~

~~As of March 31, 2021,~~2022, we have ~~WTI put options~~hedged 90,000 bopd with ~~an average monthly floor price of $55 per barrel for 120,000 bopd, and Brent~~WTI put options with an average monthly floor price of $60 per barrel, ~~for 30,000~~and 60,000 bopd ~~for the remainder~~with Brent put options with an average monthly floor price of ~~the year.~~$65 per barrel. We expect noncash ~~put option~~ premium amortization, which will be reflected in realized selling prices, to reduce our second, third and fourth quarter results each by ~~$64 million~~approximately $165 million.

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,
	2022		2021

	(In thousands)
Crude Oil – Barrels
United States
North Dakota	77		84
Offshore	22		36
Total United States	99		120
Guyana	30		31
Malaysia and JDA	3		4
Other (a)	19		22
Total	151		177
Natural Gas Liquids – Barrels
United States
North Dakota	49		49
Offshore	1		4
Total United States	50		53
Natural Gas – Mcf
United States
North Dakota	158		151
Offshore	43		95
Total United States	201		246
Malaysia and JDA	364		360
Other (a)	12		11
Total	577		617
Barrels of Oil Equivalent (b)	297		333

Crude oil and natural gas liquids as a share of total production	68	%	69	%

(a)Other includes Libya and our former interests in Denmark, which were sold in the third quarter of 2021. Net production from Libya was 21,000 boepd in the first quarter of 2022 compared with 18,000 boepd in the first quarter of 2021. Net production from Denmark was 6,000 boepd in the first quarter of 2021.

(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 19.

We forecast net production, excluding Libya, to be approximately 310,000 boepd for the second quarter and at the low end of the range of 325,000 boepd to 330,000 boepd for the full year 2022 reflecting our initial assessment of the impact from severe weather in North Dakota in April.

United States: North Dakota net production was lower in the first quarter of 2022, compared to the year-ago quarter, primarily due to the sale of Little Knife and Murphy Creek nonstrategic acreage interests in the second quarter of 2021, ~~results~~which contributed net production of approximately 5,000 boepd in the first quarter of 2021. Total offshore net production was lower in the first quarter of 2022, compared to the year-ago quarter, primarily due to field decline and unplanned downtime at the Baldpate, Penn State, and Llano fields.

International: Net production in Guyana was lower in the first quarter of 2022 by ~~approximately $245 million.~~

1,000 bopd, compared to the year-ago quarter, due to the planned downtime on the Liza Destiny FPSO for production optimization work in the first quarter of 2022. In February 2022, production commenced from the Liza Unity FPSO and averaged 7,000 net bopd in the first quarter of 2022.

2120

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

~~Production~~Sales 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~~Lower sales volumes in the first quarter of ~~2021~~2022, reduced after-tax earnings by approximately $260 million compared ~~with 5,000 boepd~~to the same period in ~~the first quarter~~2021. Worldwide sales volumes from Hess net production, which excludes sales volumes of ~~2020. Net production form Denmark was 6,000 boepd in~~crude oil, NGLs and natural gas purchased from third parties, were as follows:


	Three Months Ended March 31,
	2022	2021

	(In thousands)
Crude oil – barrels (a)	12,580	20,395
Natural gas liquids – barrels	4,539	4,802
Natural gas – mcf	51,898	55,513
Barrels of Oil Equivalent (b)	25,769	34,449
Crude oil – barrels per day	140	227
Natural gas liquids – barrels per day	50	53
Natural gas – mcf per day	577	617
Barrels of Oil Equivalent Per Day (b)	286	383

(a)Sales volumes for the first quarter of 2021 ~~compared with 7,000 boepd in the first quarter of~~include 4.2 million barrels that were produced and stored on VLCCs during 2020.

~~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.

~~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 21.19.

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,~~2022, compared with the corresponding period in ~~2020,~~2021, primarily due to higher ~~benchmark~~third party crude oil volumes purchased and prices onpaid for purchased ~~volumes and the inclusion of~~volumes. First quarter 2021 marketing expense included $173 million ~~for~~related to the cost of ~~the~~ 4.2 million barrels of crude oil stored on two VLCCs in 2020 that were sold in the ~~quarter.~~first quarter of 2021.

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~~increased 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,~~2022 compared with the corresponding period in ~~2020,~~2021, primarily due to production commencing in February at Liza Phase 2 in Guyana and higher production and severance taxes associated with higher crude oil prices. On a per-unit basis, cash operating costs in the first quarter of 2022 reflect the higher costs and the impact of the lower production ~~volumes.~~volumes compared with the corresponding period in 2021.

Midstream Tariffs Expense: Tariffs expense increased in the first quarter of ~~2021,~~2022, compared with the corresponding period in ~~2020,~~2021, primarily due to higher minimum volume ~~commitments and tariff rates.~~commitments. We estimate Midstream tariffs expense to be in the range of ~~$260~~$290 million and ~~$270~~$300 million in the second quarter of ~~2021~~2022 and in the range of ~~$1,090~~$1,190 million and ~~$1,115~~$1,215 million for the full year ~~2021.~~2022.

Depreciation, Depletion and Amortization (DD&A): DD&A expense ~~and per unit rates were~~was lower in the first quarter of ~~2021,~~2022, compared with the ~~prior-year~~corresponding period in 2021, primarily due to ~~the impact of first quarter 2020 impairment charges~~lower production volumes and lower DD&A rates resulting from year-end ~~2020 revisions and~~2021 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)			Actual				Forecast range (a)
		Three Months Ended March 31,				Three Months Ended June 30,	Twelve Months Ended December 31,		Three Months Ended March 31,					Three Months Ended June 30,	Twelve Months Ended December 31,
		2021		2020		2021	2021		2022		2021				2022	2022
Cash operating costs (b)	Cash operating costs (b)	$	9.81	$	9.70	$12.00 — $13.00	$11.00 — $12.00	Cash operating costs (b)	$	13.79	$	9.81			$15.00 — $15.50	$13.50 — $14.00
DD&A (c)	DD&A (c)	11.83		16.44		11.50 — 12.50	12.00 — 13.00	DD&A (c)	10.96		11.83				12.00 — 12.50	11.50 — 12.50
Total Production Unit Costs	Total Production Unit Costs	$	21.64	$	26.14	$23.50 — $25.50	$23.00 — $25.00	Total Production Unit Costs	$	24.75	$	21.64			$27.00 — $28.00	$25.00 — $26.50

(a)Forecast information excludes any contribution from Libya.

(b)Cash operating costs per boe, excluding Libya, were $14.54 in the first quarter of 2022, compared with $10.21 in the first quarter of ~~2021, compared with $9.61 in the first quarter of 2020.~~2021.

(c)DD&A per boe, excluding Libya, was $11.54 in the first quarter of 2022, compared with $12.36 in the first quarter of ~~2021, compared with $16.64 in the first quarter of 2020.~~2021.

2321

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.~~


	Three Months Ended March 31,
	2022		2021

	(In millions)

Exploration lease and other impairment	$	6	$	4
Geological and geophysical expense and exploration overhead	37		29
Total Exploration Expense	$	43	$	33

Exploration expenses, excluding dry hole expense, are estimated to be in the range of ~~$40~~$35 million to ~~$45~~$40 million in the second quarter of ~~2021~~2022 and in the range of $170 million toand $180 million for the full year ~~2021.~~2022.

Income Taxes:

E&P income tax expense was $192 million in the first quarter of 2022 and $120 million in the first quarter of 2021. The increase in income tax expense ~~in the first quarter of 2021, compared to the corresponding period in 2020, is~~was 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~~Income tax expense from Libya operations was $154 million in ~~the~~ first quarter of ~~2021 was $40 million,~~2022 compared with $9$80 million in ~~the~~ first quarter of ~~2020.~~2021. We are generally not recognizing deferred tax benefit or expense in certain countries, primarily the U.S. (non-Midstream), and Malaysia, while we maintain valuation allowances against net deferred tax assets in these jurisdictions in accordance with the requirements of U.S. accounting standards. Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense is expected to be in the range of ~~$25~~$135 million to ~~$30~~$140 million for the second quarter of ~~2021~~2022 and ~~$105~~in the range of $460 million ~~to $115~~and $470 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.~~

~~PART I - FINANCIAL INFORMATION (CONT'D.)~~

~~Consolidated Results of Operations (continued)~~2022.

Midstream

Following is a summarized income statement for our Midstream operations:


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Revenues and Non-Operating Income	Revenues and Non-Operating Income					Revenues and Non-Operating Income
Sales and other operating revenues	Sales and other operating revenues	$	289	$	291	Sales and other operating revenues	$	312	$	289
Other, net	Other, net	3		2		Other, net	1		3
Total revenues and non-operating income	Total revenues and non-operating income	292		293		Total revenues and non-operating income	313		292
Costs and Expenses	Costs and Expenses					Costs and Expenses
Operating costs and expenses	Operating costs and expenses	60		92		Operating costs and expenses	66		60
General and administrative expenses	General and administrative expenses	7		8		General and administrative expenses	6		7
Interest expense	Interest expense	23		25		Interest expense	31		23
Depreciation, depletion and amortization	Depreciation, depletion and amortization	40		38		Depreciation, depletion and amortization	45		40
Total costs and expenses	Total costs and expenses	130		163		Total costs and expenses	148		130
Results of Operations Before Income Taxes	Results of Operations Before Income Taxes	162		130		Results of Operations Before Income Taxes	165		162
Provision (benefit) for income taxes	Provision (benefit) for income taxes	3		2		Provision (benefit) for income taxes	5		3
Net Income (Loss)	Net Income (Loss)	159		128		Net Income (Loss)	160		159
Less: Net income (loss) attributable to noncontrolling interests	Less: Net income (loss) attributable to noncontrolling interests	84		67		Less: Net income (loss) attributable to noncontrolling interests	88		84
Net Income (Loss) Attributable to Hess Corporation	Net Income (Loss) Attributable to Hess Corporation	$	75	$	61	Net Income (Loss) Attributable to Hess Corporation	$	72	$	75

Sales and other operating revenues ~~were lower in~~for the first quarter of ~~2021,~~2022 increased, compared to the ~~corresponding period in 2020,~~prior-year quarter, primarily ~~due to lower pass-through rail transportation revenue partially offset by~~associated with higher minimum volume ~~commitments and tariff rates.~~ commitments.

Operating costs and expenses for the first quarter of ~~2021 decreased,~~2022 increased, compared to the ~~corresponding period in 2020,~~prior-year quarter, primarily due to ~~lower pass-through~~higher rail transportation costs. DD&A expense for the first quarter of 2022 increased, compared to the prior-year quarter, primarily due to additional assets placed in service. Interest expense for the first quarter of 2022 increased, compared to the prior-year quarter, primarily due to the $750 million of 4.250% fixed-rate senior unsecured notes issued in August 2021.

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~~and $65 million in the second quarter of ~~2021~~2022 and in the range of ~~$280~~$265 million and ~~$290~~$275 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.

2022.

2522

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Corporate, Interest and Other

The following table summarizes Corporate, Interest and Other expenses:


	Three Months Ended March 31,
	2022		2021

	(In millions)
Corporate and other expenses	$	36	$	37
Interest expense	92		94
Corporate, Interest and Other expenses before income taxes	128		131
Provision (benefit) for income taxes	—		—
Net Corporate, Interest and Other expenses after income taxes	128		131
Items affecting comparability of earnings between periods, after-tax	(13)		—
Total Corporate, Interest and Other Expenses after income taxes	$	115	$	131

Second quarter 2022 corporate expenses are expected to be approximately $30 million and in the range of $120 million and $130 million for the full year 2022. Interest expense is expected to be in the range of $85 million to $90 million for the second quarter and in the range of $345 million and $355 million for the full year 2022.

Items Affecting Comparability of Earnings Between Periods:First quarter 2022 results included a pre-tax gain of $22 million ($22 million after income taxes) associated with the sale of property and a charge of $9 million ($9 million after income taxes) for litigation related to our former downstream business.

Other Items Potentially Affecting Future ~~Results:~~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.~~the global COVID-19 pandemic (COVID-19). For a more comprehensive description of the risks that may affect our business, see Item1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021.

Liquidity and Capital Resources

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


		March 31, 2021			December 31, 2020				March 31, 2022			December 31, 2021

		(In millions, except ratio)							(In millions, except ratio)
Cash and cash equivalents (a)	Cash and cash equivalents (a)	$	1,866		$	1,739		Cash and cash equivalents (a)	$	1,370		$	2,713
Current maturities of long-term debt		13			10
Current portion of long-term debt								Current portion of long-term debt	22			517
Total debt (b)	Total debt (b)	8,286			8,296			Total debt (b)	7,956			8,458
Total equity	Total equity	6,643			6,335			Total equity	7,048			7,026
Debt to capitalization ratio (c)		46.6		%	47.5		%
Debt to capitalization ratio for debt covenants (c)								Debt to capitalization ratio for debt covenants (c)	40.2		%	42.3		%

(a)Includes $4 million of cash attributable to our Midstream segment at March 31, ~~2021~~2022 (December 31, ~~2020: $4~~2021: $2 million) of which, $2$3 million is held by Hess Midstream LP at March 31, ~~2021~~2022 (December 31, ~~2020: $3~~2021: $2 million).

(b)At March 31, ~~2021,~~2022, includes ~~$1,899~~$2,561 million of debt outstanding from our Midstream segment (December 31, ~~2020: $1,910~~2021: $2,564 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.

2623

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

Cash Flows

The following table summarizes our cash flows:


	Three Months Ended March 31,
	2022		2021

	(In millions)
Net cash provided by (used in):
Operating activities	$	(156)	$	591
Investing activities	(522)		(385)
Financing activities	(665)		(79)
Net Increase (Decrease) in Cash and Cash Equivalents	$	(1,343)	$	127

Operating activities: Net cash used in operating activities was $156 million in the first quarter of 2022, compared with net cash provided by operating activities of $591 million in the first quarter of 2021. Net cash provided by operating activities before changes in operating assets and liabilities was $952 million in the first quarter of 2022, compared with $815 million in the prior-year quarter primarily due to higher realized selling prices, partially offset by the impact of lower sales volumes. During the first quarter of 2022, changes in operating assets and liabilities reduced net cash provided by operating activities by $1,108 million, reflecting payments made for previously accrued Libyan income tax and royalties of approximately $470 million for the period December 2020 through November 2021, premiums paid of $325 million to remove the ceiling price on outstanding WTI and Brent crude oil collars effective April 1, 2022, and an increase in accounts receivable due to higher crude oil prices. During the first quarter of 2021, changes in operating assets and liabilities decreased cash flow from operating activities by $224 million.

Investing activities: Additions to property, plant and equipment of $546 million in the first quarter of 2022 were up $161 million compared with the corresponding period in 2021. The increase is primarily due to higher drilling and development activities in Guyana, the Bakken, and Malaysia and JDA.

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


		Three Months Ended March 31,					Three Months Ended March 31,
		2021		2020			2022		2021

		(In millions)					(In millions)
Additions to property, plant and equipment - E&P:	Additions to property, plant and equipment - E&P:					Additions to property, plant and equipment - E&P:
Capital expenditures incurred - E&P	Capital expenditures incurred - E&P	$	(280)	$	(609)	Capital expenditures incurred - E&P	$	(543)	$	(280)
Increase (decrease) in related liabilities	Increase (decrease) in related liabilities	(78)		(131)		Increase (decrease) in related liabilities	52		(78)
Additions to property, plant and equipment - E&P	Additions to property, plant and equipment - E&P	$	(358)	$	(740)	Additions to property, plant and equipment - E&P	$	(491)	$	(358)
Additions to property, plant and equipment - Midstream:	Additions to property, plant and equipment - Midstream:					Additions to property, plant and equipment - Midstream:
Capital expenditures incurred - Midstream	Capital expenditures incurred - Midstream	$	(23)	$	(57)	Capital expenditures incurred - Midstream	$	(37)	$	(23)
Increase (decrease) in related liabilities	Increase (decrease) in related liabilities	(4)		(21)		Increase (decrease) in related liabilities	(18)		(4)
Additions to property, plant and equipment - Midstream	Additions to property, plant and equipment - Midstream	$	(27)	$	(78)	Additions to property, plant and equipment - Midstream	$	(55)	$	(27)

Financing activities: ~~Hess Midstream repaid a net total of $10 million from its revolving credit facilities in~~In the first quarter of ~~2021 and borrowed a net total of $60~~2022, we repaid the remaining $500 million outstanding under our $1 billion term loan previously scheduled to mature in March 2023. Common stock dividends paid were $119 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~~2022, compared to $80 million in the first quarter of ~~2021, compared~~2021. Net cash outflows to ~~$81~~noncontrolling interests were $74 million in the first quarter of ~~2020. In addition, net cash outflows to noncontrolling interests were~~2022 and $67 million in the first quarter of ~~2021 and $63 million in the first quarter of 2020.~~2021. 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.

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

Future Capital Requirements and Resources

At March 31, ~~2021,~~2022, we had ~~$1.86~~$1.37 billion in cash and cash equivalents, excluding Midstream, and total liquidity, including available committed credit facilities, of approximately ~~$5.5~~$4.94 billion. ~~On April 13, 2021,~~In March 2022, we ~~amended the Corporation's fully undrawn $3.5 billion revolving credit facility by extending the facility's expiration date for one year~~announced a 50% increase in our first quarter dividend on common stock. As we become increasingly free cash flow positive, we plan to ~~May 2024. Oil and gas production in 2021, excluding Libya, is forecast~~return up 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~~75% 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~~annual adjusted free cash flow 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.~~shareholders through further dividend increases and/or common stock repurchases.

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,~~2022, 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~~2022, will be sufficient to fund our capital investment ~~program~~ and ~~dividends. We~~capital return programs. Depending on market conditions, 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.

~~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:~~2022:


		Expiration Date	Capacity		Borrowings		Letters of Credit Issued		Total Used		Available Capacity			Expiration Date	Capacity		Borrowings		Letters of Credit Issued		Total Used		Available Capacity

			(In millions)												(In millions)
Hess Corporation	Hess Corporation												Hess Corporation
Revolving credit facility	Revolving credit facility	May, 2023	$	3,500	$	—	$	—	$	—	$	3,500	Revolving credit facility	May 2024	$	3,500	$	—	$	—	$	—	$	3,500
Committed lines	Committed lines	Various (a)	175		—		54		54		121		Committed lines	Various (a)	100		—		29		29		71
Uncommitted lines	Uncommitted lines	Various (a)	229		—		229		229		—		Uncommitted lines	Various (a)	248		—		248		248		—
Total - Hess Corporation	Total - Hess Corporation		$	3,904	$	—	$	283	$	283	$	3,621	Total - Hess Corporation		$	3,848	$	—	$	277	$	277	$	3,571
Midstream	Midstream												Midstream
Revolving credit facility (b)	Revolving credit facility (b)	December, 2024	$	1,000	$	174	$	—	$	174	$	826	Revolving credit facility (b)	December 2024	$	1,000	$	105	$	—	$	105	$	895
Total - Midstream	Total - Midstream		$	1,000	$	174	$	—	$	174	$	826	Total - Midstream		$	1,000	$	105	$	—	$	105	$	895

(a)Committed and uncommitted lines have expiration dates through ~~2021.~~2022.

(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~~The 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~~is 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)~~facility). 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%. AtAs of March 31, ~~2021,~~2022, 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 credit rating. In March ~~2021,~~2022, Standard and Poor’s Ratings Services affirmed our credit rating at BBB- with stable outlook. Fitch Ratings affirmed our BBB- credit rating and revised the outlook from stable to ~~stable (from negative). Fitch Ratings affirmed a BBB- credit rating and stable outlook~~positive in August ~~2020~~2021 and Moody’s Investors Service affirmed our credit rating at Ba1, ~~with stable outlook,~~ which is below investment grade, and revised the outlook from stable to positive in ~~March 2020.~~November 2021.

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~~2022, HESM ~~Opco),~~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~~$1 billion ~~5-year~~five year revolving credit facility and a fully drawn $400 million ~~5-year~~five 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 HESM Opco to maintain a ratio of total debt to EBITDA (as defined in the

2825

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.~~2022. The credit facilities are secured by first-priority perfected liens on substantially all of 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,~~2022, borrowings of ~~$174~~$105 million were drawn under HESM Opco’s revolving credit facility, and borrowings of ~~$398~~$385 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~~$156 million at March 31, ~~2021~~2022 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 gain or loss, ~~or gain~~respectively, of ~~less than $5~~approximately $15 million ~~respectively,~~ at March 31, ~~2021.~~2022.

At March 31, ~~2021, our total~~2022, consolidated long-term debt, which was substantially comprised of fixed-rate instruments, had a carrying value of ~~$8,286~~$7,956 million and a fair value of ~~$9,381~~$8,801 million. A 15% increase or decrease in interest rates would decrease or increase the fair value of debt by approximately ~~$405~~$420 million or ~~$420~~$440 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,~~2022, we have ~~outstanding~~ WTI put options with an average monthly floor price of $60 per barrel for 90,000 bopd, and Brent ~~crude oil~~ put ~~option contracts.~~options with an average monthly floor price of $65 per barrel for 60,000 bopd. As of March 31, ~~2021,~~2022, an assumed 10% increase in the forward WTI and Brent crude oil prices used in determining the fair value of our put options would reduce the fair value of these derivative instruments by approximately ~~$50~~$15 million, while an assumed 10% decrease in the same crude oil prices would increase the fair value of these derivative instruments by approximately ~~$110~~$20 million.

2926

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~~natural gas liquids and natural gas and our associated realized price differentials; our projected budget and capital and exploratory expenditures; expected timing and completion of our development ~~projects and proposed asset sale;~~projects; and future economic and market conditions in the oil and gas industry.

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

•fluctuations in market prices of crude oil, ~~NGL~~natural gas liquids 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, orperceptions regarding the ~~outbreak of any other public health threat, or due to the impact of~~oil and gas industry, 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, fracking bans as well as ~~fracking bans;~~restrictions on oil and gas leases;

•operational changes and expenditures due to climate change and sustainability related initiatives;

•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;~~COVID-19, or climate change;

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

•control and exposure to decommissioning liabilities for divested assets in the ~~ability~~event the current or future owners are unable to ~~satisfy the closing conditions of the proposed asset sale;~~perform;

•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~~limitations on investment in ~~the~~ oil and gas ~~industry~~activities or negative outcomes within commodity and financial markets;

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

•other factors described in the section entitled “Risk Factors” in Item ~~1A.~~ 1A—Risk Factors in our Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 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.

3027

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,~~2022, 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.~~2022.

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~~2022 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

3128

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.

3229

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~~202 4 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,~~2022, has been formatted in Inline XBRL.

*The exhibit relates to executive compensation plans and arrangements.

3330

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~~5, 2022

3431


	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)