~~0000004447hes:ExplorationAndProductionMemberus-gaap:IntersegmentEliminationMembercountry:LY2022-04-012022-06-30~~

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

☒

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

For the quarter ended June 30, ~~2022~~2023


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

For the transition period from to

Commission File Number 1-1204

HESS CORPORATION

(Exact Name of Registrant as Specified in Its Charter)

DELAWARE

(State or Other Jurisdiction of Incorporation or Organization)

13-4921002

(I.R.S. Employer Identification Number)

1185 AVENUE OF THE AMERICAS, NEW YORK, NY

(Address of Principal Executive Offices)

10036

(Zip Code)

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

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


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

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

At June 30, ~~2022,~~2023, there were ~~309,614,906~~307,061,031 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 June 3 0 , 2022, and December 31, 2021	2
		Statement of Consolidated Income for the Three and Six Months Ended June 3 0 , 2022, and 2021	3
		Statement of Consolidated Comprehensive Income for the Three and Six Months Ended June 3 0 , 2022, and 2021	4		Consolidated Balance Sheet at June 3 0 , 2023, and December 31, 2022	2
		Statement of Consolidated Cash Flows for the Six Months Ended June 3 0 , 2022, and 2021	5		Statement of Consolidated Income for the Three and Six Months Ended June 3 0 , 2023, and 2022	3
		Statement of Consolidated Equity for the Three and Six Months Ended June 3 0 , 2022, and 2021	6		Statement of Consolidated Comprehensive Income for the Three and Six Months Ended June 3 0 , 2023, and 2022	4
		Notes to Consolidated Financial Statements (Unaudited)	7		Statement of Consolidated Cash Flows for the Six Months Ended June 3 0 , 2023, and 2022	5
		Note 1 - Basis of Presentation	7		Statement of Consolidated Equity for the T hree and Six Months Ended June 3 0 , 2023, and 2022	6
		Note 2 - Inventories	7		Notes to Consolidated Financial Statements (Unaudited)	7
		Note 3 - Property, Plant and Equipment	7		Note 1 - Basis of Presentation	7
		Note 4 - Hess Midstream LP	8		Note 2 - Inventories	7
		Note 5 - Accrued Liabilities	8		Note 3 - Property, Plant and Equipment	7
		Note 6 - Debt	8		Note 4 - Hess Midstream LP	8
		Note 7 - Revenue	9		Note 5 - Accrued Liabilities	9
		Note 8 - Impairment and Other	10		Note 6 - Revenue	10
		Note 9 - Retirement Plans	10		Note 7 - Impairment and Other	11
		Note 10 - Weighted Average Common Shares	11		Note 8 - Retirement Plans	11
		Note 1 1 - Guarantees and Contingencies	11		Note 9 - Weighted Average Common Shares	11
		Note 1 2 - Segment Information	14		Note 10 - Guarantees and Contingencies	12
		Note 1 3 - Financial Risk Management Activities	15		Note 1 1 - Segment Information	14
		Note 1 4 - Subsequent Events	17		Note 1 2 - Financial Risk Management Activities	15

2.	2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	18	2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	17
3.	3.	Quantitative and Qualitative Disclosures about Market Risk	32	3.	Quantitative and Qualitative Disclosures about Market Risk	31
4.	4.	Controls and Procedures	32	4.	Controls and Procedures	31

		PART II - OTHER INFORMATION			PART II - OTHER INFORMATION
1.	1.	Legal Proceedings	33	1.	Legal Proceedings	32
2.	2.	Share Repurchase Activities	33	2.	Share Repurchase Activities	32
5 .				5 .	Other Information	32
6.	6.	Exhibits	34	6.	Exhibits	33
		Signatures	35		Signatures	34

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

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED BALANCE SHEET (UNAUDITED)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022

		(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	$	2,159	$	2,713	Cash and cash equivalents	$	2,226	$	2,486
Accounts receivable:	Accounts receivable:					Accounts receivable:
From contracts with customers	From contracts with customers	1,265		1,062		From contracts with customers	868		1,041
Joint venture and other	Joint venture and other	141		149		Joint venture and other	151		121
Inventories	Inventories	317		223		Inventories	278		217
Other current assets	Other current assets	87		199		Other current assets	181		66
Total current assets	Total current assets	3,969		4,346		Total current assets	3,704		3,931
Property, plant and equipment:	Property, plant and equipment:					Property, plant and equipment:
Total — at cost	Total — at cost	32,402		31,178		Total — at cost	34,073		32,592
Less: Reserves for depreciation, depletion, amortization and lease impairment	Less: Reserves for depreciation, depletion, amortization and lease impairment	17,584		16,996		Less: Reserves for depreciation, depletion, amortization and lease impairment	18,332		17,494
Property, plant and equipment — net	Property, plant and equipment — net	14,818		14,182		Property, plant and equipment — net	15,741		15,098
Operating lease right-of-use assets — net	Operating lease right-of-use assets — net	446		352		Operating lease right-of-use assets — net	515		570
Finance lease right-of-use assets — net	Finance lease right-of-use assets — net	136		144		Finance lease right-of-use assets — net	117		126
Goodwill	Goodwill	360		360		Goodwill	360		360
Deferred income taxes	Deferred income taxes	147		71		Deferred income taxes	214		133
Post-retirement benefit assets	Post-retirement benefit assets	603		409		Post-retirement benefit assets	664		648
Other assets	Other assets	701		651		Other assets	915		829
Total Assets	Total Assets	$	21,180	$	20,515	Total Assets	$	22,230	$	21,695
Liabilities	Liabilities					Liabilities
Current Liabilities:	Current Liabilities:					Current Liabilities:
Accounts payable	Accounts payable	$	359	$	220	Accounts payable	$	350	$	285
Accrued liabilities	Accrued liabilities	1,741		1,710		Accrued liabilities	1,754		1,840
Taxes payable	Taxes payable	141		528		Taxes payable	69		47
Current portion of long-term debt	Current portion of long-term debt	—		517		Current portion of long-term debt	8		3
Current portion of operating and finance lease obligations	Current portion of operating and finance lease obligations	114		89		Current portion of operating and finance lease obligations	222		221
Total current liabilities	Total current liabilities	2,355		3,064		Total current liabilities	2,403		2,396
Long-term debt	Long-term debt	8,332		7,941		Long-term debt	8,459		8,278
Long-term operating lease obligations	Long-term operating lease obligations	457		394		Long-term operating lease obligations	407		469
Long-term finance lease obligations	Long-term finance lease obligations	190		200		Long-term finance lease obligations	168		179
Deferred income taxes	Deferred income taxes	544		383		Deferred income taxes	497		418
Asset retirement obligations	Asset retirement obligations	1,028		1,005		Asset retirement obligations	960		1,034
Other liabilities and deferred credits	Other liabilities and deferred credits	516		502		Other liabilities and deferred credits	434		425
Total Liabilities	Total Liabilities	13,422		13,489		Total Liabilities	13,328		13,199
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 309,614,906 shares (2021: 309,744,953)		310		310
Issued 307,061,031 shares (2022: 306,176,864)						Issued 307,061,031 shares (2022: 306,176,864)	307		306
Capital in excess of par value	Capital in excess of par value	6,236		6,017		Capital in excess of par value	6,442		6,206
Retained earnings	Retained earnings	1,075		379		Retained earnings	1,670		1,474
Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss)	(485)		(406)		Accumulated other comprehensive income (loss)	(147)		(131)
Total Hess Corporation stockholders’ equity	Total Hess Corporation stockholders’ equity	7,136		6,300		Total Hess Corporation stockholders’ equity	8,272		7,855
Noncontrolling interests	Noncontrolling interests	622		726		Noncontrolling interests	630		641
Total Equity	Total Equity	7,758		7,026		Total Equity	8,902		8,496
Total Liabilities and Equity	Total Liabilities and Equity	$	21,180	$	20,515	Total Liabilities and Equity	$	22,230	$	21,695

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 June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(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	$	2,955	$	1,579	$	5,268	$	3,477	Sales and other operating revenues	$	2,289	$	2,955	$	4,700	$	5,268
Gains on asset sales, net	Gains on asset sales, net	3		—		25		—		Gains on asset sales, net	—		3		—		25
Other, net	Other, net	30		19		66		40		Other, net	31		30		73		66
Total revenues and non-operating income	Total revenues and non-operating income	2,988		1,598		5,359		3,517		Total revenues and non-operating income	2,320		2,988		4,773		5,359
Costs and Expenses	Costs and Expenses									Costs and Expenses
Marketing, including purchased oil and gas	Marketing, including purchased oil and gas	843		322		1,525		840		Marketing, including purchased oil and gas	547		843		1,150		1,525
Operating costs and expenses	Operating costs and expenses	356		315		669		580		Operating costs and expenses	454		356		836		669
Production and severance taxes	Production and severance taxes	67		44		128		81		Production and severance taxes	46		67		94		128
Exploration expenses, including dry holes and lease impairment	Exploration expenses, including dry holes and lease impairment	33		48		76		81		Exploration expenses, including dry holes and lease impairment	99		33		165		76
General and administrative expenses	General and administrative expenses	95		84		205		178		General and administrative expenses	108		95		244		205
Interest expense	Interest expense	121		118		244		235		Interest expense	122		121		245		244
Depreciation, depletion and amortization	Depreciation, depletion and amortization	391		385		728		781		Depreciation, depletion and amortization	497		391		988		728
Impairment and other	Impairment and other	—		147		—		147		Impairment and other	82		—		82		—
Total costs and expenses	Total costs and expenses	1,906		1,463		3,575		2,923		Total costs and expenses	1,955		1,906		3,804		3,575
Income (Loss) Before Income Taxes		1,082		135		1,784		594
Provision (benefit) for income taxes		328		122		525		245
Net Income (Loss)		754		13		1,259		349
Less: Net income (loss) attributable to noncontrolling interests		87		86		175		170
Net Income (Loss) Attributable to Hess Corporation		$	667	$	(73)	$	1,084	$	179
Income Before Income Taxes										Income Before Income Taxes	365		1,082		969		1,784
Provision for income taxes										Provision for income taxes	160		328		336		525
Net Income										Net Income	205		754		633		1,259
Less: Net income attributable to noncontrolling interests										Less: Net income attributable to noncontrolling interests	86		87		168		175
Net Income Attributable to Hess Corporation										Net Income Attributable to Hess Corporation	$	119	$	667	$	465	$	1,084

Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Net Income Attributable to Hess Corporation Per Common Share:										Net Income Attributable to Hess Corporation Per Common Share:
Basic	Basic	$	2.15	$	(0.24)	$	3.50	$	0.58	Basic	$	0.39	$	2.15	$	1.52	$	3.50
Diluted	Diluted	$	2.15	$	(0.24)	$	3.49	$	0.58	Diluted	$	0.39	$	2.15	$	1.51	$	3.49
Weighted Average Number of Common Shares Outstanding:	Weighted Average Number of Common Shares Outstanding:									Weighted Average Number of Common Shares Outstanding:
Basic	Basic	309.7		307.5		309.3		306.7		Basic	306.0		309.7		305.7		309.3
Diluted	Diluted	310.9		307.5		310.6		308.7		Diluted	307.5		310.9		307.4		310.6
Common Stock Dividends Per Share	Common Stock Dividends Per Share	$	0.375	$	0.250	$	0.750	$	0.500	Common Stock Dividends Per Share	$	0.4375	$	0.3750	$	0.8750	$	0.7500

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 June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In millions)									(In millions)
Net Income (Loss)		$	754	$	13	$	1,259	$	349
Net Income										Net Income	$	205	$	754	$	633	$	1,259
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	163		64		255		115		Effect of hedge (gains) losses reclassified to income	52		163		86		255
Income taxes on effect of hedge (gains) losses reclassified to income	Income taxes on effect of hedge (gains) losses reclassified to income	—		—		—		—		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	163		64		255		115		Net effect of hedge (gains) losses reclassified to income	52		163		86		255
Change in fair value of cash flow hedges	Change in fair value of cash flow hedges	(39)		(129)		(494)		(231)		Change in fair value of cash flow hedges	(73)		(39)		(90)		(494)
Income taxes on change in fair value of cash flow hedges	Income taxes on change in fair value of cash flow hedges	—		—		—		—		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	(39)		(129)		(494)		(231)		Net change in fair value of cash flow hedges	(73)		(39)		(90)		(494)
Change in derivatives designated as cash flow hedges, after taxes	Change in derivatives designated as cash flow hedges, after taxes	124		(65)		(239)		(116)		Change in derivatives designated as cash flow hedges, after taxes	(21)		124		(4)		(239)
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	152		(11)		152		3		(Increase) reduction in unrecognized actuarial losses	(13)		152		(13)		152
Income taxes on actuarial changes in plan liabilities	Income taxes on actuarial changes in plan liabilities	—		—		—		—		Income taxes on actuarial changes in plan liabilities	—		—		—		—
(Increase) reduction in unrecognized actuarial losses, net	(Increase) reduction in unrecognized actuarial losses, net	152		(11)		152		3		(Increase) reduction in unrecognized actuarial losses, net	(13)		152		(13)		152
Amortization of net actuarial losses	Amortization of net actuarial losses	5		16		8		32		Amortization of net actuarial losses	1		5		1		8
Income taxes on amortization of net actuarial losses	Income taxes on amortization of net actuarial losses	—		—		—		—		Income taxes on amortization of net actuarial losses	—		—		—		—
Net effect of amortization of net actuarial losses	Net effect of amortization of net actuarial losses	5		16		8		32		Net effect of amortization of net actuarial losses	1		5		1		8
Change in pension and other postretirement plans, after taxes	Change in pension and other postretirement plans, after taxes	157		5		160		35		Change in pension and other postretirement plans, after taxes	(12)		157		(12)		160
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss)	281		(60)		(79)		(81)		Other Comprehensive Income (Loss)	(33)		281		(16)		(79)
Comprehensive Income (Loss)		1,035		(47)		1,180		268
Less: Comprehensive income (loss) attributable to noncontrolling interests		87		86		175		170
Comprehensive Income (Loss) Attributable to Hess Corporation		$	948	$	(133)	$	1,005	$	98
Comprehensive Income										Comprehensive Income	172		1,035		617		1,180
Less: Comprehensive income attributable to noncontrolling interests										Less: Comprehensive income attributable to noncontrolling interests	86		87		168		175
Comprehensive Income Attributable to Hess Corporation										Comprehensive Income Attributable to Hess Corporation	$	86	$	948	$	449	$	1,005

See accompanying Notes to Consolidated Financial Statements.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED CASH FLOWS (UNAUDITED)


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022

		(In millions)					(In millions)
Cash Flows From Operating Activities	Cash Flows From Operating Activities					Cash Flows From Operating Activities
Net income (loss)		$	1,259	$	349
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Gains) on asset sales, net		(25)		—
Net income						Net income	$	633	$	1,259
Adjustments to reconcile net income to net cash provided by (used in) operating activities:						Adjustments to reconcile net income to net cash provided by (used in) operating activities:
(Gains) losses on asset sales, net						(Gains) losses on asset sales, net	—		(25)
Depreciation, depletion and amortization	Depreciation, depletion and amortization	728		781		Depreciation, depletion and amortization	988		728
Impairment and other	Impairment and other	—		147		Impairment and other	82		—
Exploratory dry hole costs	Exploratory dry hole costs	—		9		Exploratory dry hole costs	93		—
Exploration lease and other impairment		10		10
Exploration lease impairment						Exploration lease impairment	13		10
Pension settlement loss	Pension settlement loss	2		4		Pension settlement loss	—		2
Stock compensation expense	Stock compensation expense	49		44		Stock compensation expense	53		49
Noncash (gains) losses on commodity derivatives, net	Noncash (gains) losses on commodity derivatives, net	218		88		Noncash (gains) losses on commodity derivatives, net	52		218
Provision (benefit) for deferred income taxes and other tax accruals		174		42
Provision for deferred income taxes and other tax accruals						Provision for deferred income taxes and other tax accruals	92		174
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	(529)		(315)		(Increase) decrease in accounts receivable	(14)		(529)
(Increase) decrease in inventories	(Increase) decrease in inventories	(94)		137		(Increase) decrease in inventories	(61)		(94)
Increase (decrease) in accounts payable and accrued liabilities	Increase (decrease) in accounts payable and accrued liabilities	100		(56)		Increase (decrease) in accounts payable and accrued liabilities	(119)		100
Increase (decrease) in taxes payable	Increase (decrease) in taxes payable	(387)		187		Increase (decrease) in taxes payable	22		(387)
Changes in other operating assets and liabilities	Changes in other operating assets and liabilities	(152)		(51)		Changes in other operating assets and liabilities	(222)		(152)
Net cash provided by (used in) operating activities	Net cash provided by (used in) operating activities	1,353		1,376		Net cash provided by (used in) operating activities	1,612		1,353
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	(1,098)		(687)		Additions to property, plant and equipment - E&P	(1,551)		(1,098)
Additions to property, plant and equipment - Midstream	Additions to property, plant and equipment - Midstream	(111)		(53)		Additions to property, plant and equipment - Midstream	(107)		(111)
Proceeds from asset sales, net of cash sold	Proceeds from asset sales, net of cash sold	28		297		Proceeds from asset sales, net of cash sold	—		28
Other, net	Other, net	—		(2)		Other, net	(4)		—
Net cash provided by (used in) investing activities	Net cash provided by (used in) investing activities	(1,181)		(445)		Net cash provided by (used in) investing activities	(1,662)		(1,181)
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	(13)		(75)		Net borrowings (repayments) of debt with maturities of 90 days or less	180		(13)
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	400		—		Borrowings	—		400
Repayments	Repayments	(510)		(5)		Repayments	—		(510)
Cash dividends paid	Cash dividends paid	(235)		(157)		Cash dividends paid	(271)		(235)
Common stock acquired and retired	Common stock acquired and retired	(190)		—		Common stock acquired and retired	(20)		(190)
Proceeds from sale of Class A shares of Hess Midstream LP	Proceeds from sale of Class A shares of Hess Midstream LP	146		70		Proceeds from sale of Class A shares of Hess Midstream LP	167		146
Noncontrolling interests, net	Noncontrolling interests, net	(351)		(137)		Noncontrolling interests, net	(263)		(351)
Employee stock options exercised	Employee stock options exercised	40		75		Employee stock options exercised	4		40
Payments on finance lease obligations	Payments on finance lease obligations	(4)		(4)		Payments on finance lease obligations	(4)		(4)
Other, net	Other, net	(9)		(7)		Other, net	(3)		(9)
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(726)		(240)		Net cash provided by (used in) financing activities	(210)		(726)
Net Increase (Decrease) in Cash and Cash Equivalents	Net Increase (Decrease) in Cash and Cash Equivalents	(554)		691		Net Increase (Decrease) in Cash and Cash Equivalents	(260)		(554)
Cash and Cash Equivalents at Beginning of Year	Cash and Cash Equivalents at Beginning of Year	2,713		1,739		Cash and Cash Equivalents at Beginning of Year	2,486		2,713
Cash and Cash Equivalents at End of Period	Cash and Cash Equivalents at End of Period	$	2,159	$	2,430	Cash and Cash Equivalents at End of Period	$	2,226	$	2,159

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 Loss		Total Hess Stockholders' Equity		Noncontrolling Interests		Total Equity


For the Three Months Ended June 30, 2023																For the Three Months Ended June 30, 2023
Balance at April 1, 2023																Balance at April 1, 2023	$	307	$	6,254	$	1,686	$	(114)	$	8,133	$	588	$	8,721
Net income																Net income	—		—		119		—		119		86		205
Other comprehensive income (loss)																Other comprehensive income (loss)	—		—		—		(33)		(33)		—		(33)
Share-based compensation																Share-based compensation	—		19		—		—		19		—		19
Dividends on common stock																Dividends on common stock	—		—		(135)		—		(135)		—		(135)
Sale of Class A shares of Hess Midstream LP																Sale of Class A shares of Hess Midstream LP	—		158		—		—		158		93		251
Repurchase of Class B units of Hess Midstream Operations LP																Repurchase of Class B units of Hess Midstream Operations LP	—		11		—		—		11		(55)		(44)
Noncontrolling interests, net																Noncontrolling interests, net	—		—		—		—		—		(82)		(82)
Balance at June 30, 2023																Balance at June 30, 2023	$	307	$	6,442	$	1,670	$	(147)	$	8,272	$	630	$	8,902
For the Three Months Ended June 30, 2022	For the Three Months Ended June 30, 2022															For the Three Months Ended June 30, 2022
Balance at April 1, 2022	Balance at April 1, 2022	$	311	$	6,083	$	680	$	(766)	$	6,308	$	740	$	7,048	Balance at April 1, 2022	$	311	$	6,083	$	680	$	(766)	$	6,308	$	740	$	7,048
Net income (loss)		—		—		667		—		667		87		754
Net income																Net income	—		—		667		—		667		87		754
Other comprehensive income (loss)	Other comprehensive income (loss)	—		—		—		281		281		—		281		Other comprehensive income (loss)	—		—		—		281		281		—		281
Share-based compensation	Share-based compensation	1		24		—		—		25		—		25		Share-based compensation	1		24		—		—		25		—		25
Dividends on common stock	Dividends on common stock	—		—		(117)		—		(117)		—		(117)		Dividends on common stock	—		—		(117)		—		(117)		—		(117)
Sale of Class A shares of Hess Midstream LP	Sale of Class A shares of Hess Midstream LP	—		130		—		—		130		88		218		Sale of Class A shares of Hess Midstream LP	—		130		—		—		130		88		218
Repurchase of Class B units of Hess Midstream Operations LP	Repurchase of Class B units of Hess Midstream Operations LP	—		32		—		—		32		(215)		(183)		Repurchase of Class B units of Hess Midstream Operations LP	—		32		—		—		32		(215)		(183)
Common stock acquired and retired	Common stock acquired and retired	(2)		(33)		(155)		—		(190)		—		(190)		Common stock acquired and retired	(2)		(33)		(155)		—		(190)		—		(190)
Noncontrolling interests, net	Noncontrolling interests, net	—		—		—		—		—		(78)		(78)		Noncontrolling interests, net	—		—		—		—		—		(78)		(78)
Balance at June 30, 2022	Balance at June 30, 2022	$	310	$	6,236	$	1,075	$	(485)	$	7,136	$	622	$	7,758	Balance at June 30, 2022	$	310	$	6,236	$	1,075	$	(485)	$	7,136	$	622	$	7,758
For the Three Months Ended June 30, 2021
Balance at April 1, 2021		$	308	$	5,779	$	305	$	(776)	5,616		$	1,027	$	6,643
Net income (loss)		—		—		(73)		—		(73)		86		13
For the Six Months Ended June 30, 2023																For the Six Months Ended June 30, 2023
Balance at January 1, 2023																Balance at January 1, 2023	$	306	$	6,206	$	1,474	$	(131)	$	7,855	$	641	$	8,496
Net income																Net income	—		—		465		—		465		168		633
Other comprehensive income (loss)	Other comprehensive income (loss)	—		—		—		(60)		(60)		—		(60)		Other comprehensive income (loss)	—		—		—		(16)		(16)		—		(16)
Share-based compensation	Share-based compensation	2		80		—		—		82		—		82		Share-based compensation	1		59		—		—		60		—		60
Dividends on common stock	Dividends on common stock	—		—		(77)		—		(77)		—		(77)		Dividends on common stock	—		—		(269)		—		(269)		—		(269)
Sale of Class A shares of Hess Midstream LP																Sale of Class A shares of Hess Midstream LP	—		158		—		—		158		93		251
Repurchase of Class B units of Hess Midstream Operations LP																Repurchase of Class B units of Hess Midstream Operations LP	—		19		—		—		19		(109)		(90)
Noncontrolling interests, net	Noncontrolling interests, net	—		—		—		—		—		(69)		(69)		Noncontrolling interests, net	—		—		—		—		—		(163)		(163)
Balance at June 30, 2021		$	310	$	5,859	$	155	$	(836)	$	5,488	$	1,044	$	6,532
Balance at June 30, 2023																Balance at June 30, 2023	$	307	$	6,442	$	1,670	$	(147)	$	8,272	$	630	$	8,902
For the Six Months Ended June 30, 2022	For the Six Months Ended June 30, 2022															For the Six Months Ended June 30, 2022
Balance at January 1, 2022	Balance at January 1, 2022	$	310	$	6,017	$	379	$	(406)	$	6,300	$	726	$	7,026	Balance at January 1, 2022	$	310	$	6,017	$	379	$	(406)	$	6,300	$	726	$	7,026
Net income (loss)		—		—		1,084		—		1,084		175		1,259
Net income																Net income	—		—		1,084		—		1,084		175		1,259
Other comprehensive income (loss)	Other comprehensive income (loss)	—		—		—		(79)		(79)		—		(79)		Other comprehensive income (loss)	—		—		—		(79)		(79)		—		(79)
Share-based compensation	Share-based compensation	2		90		—		—		92		—		92		Share-based compensation	2		90		—		—		92		—		92
Dividends on common stock	Dividends on common stock	—		—		(233)		—		(233)		—		(233)		Dividends on common stock	—		—		(233)		—		(233)		—		(233)
Sale of Class A shares of Hess Midstream LP	Sale of Class A shares of Hess Midstream LP	—		130		—		—		130		88		218		Sale of Class A shares of Hess Midstream LP	—		130		—		—		130		88		218
Repurchase of Class B units of Hess Midstream Operations LP	Repurchase of Class B units of Hess Midstream Operations LP	—		32		—		—		32		(215)		(183)		Repurchase of Class B units of Hess Midstream Operations LP	—		32		—		—		32		(215)		(183)
Common stock acquired and retired	Common stock acquired and retired	(2)		(33)		(155)		—		(190)		—		(190)		Common stock acquired and retired	(2)		(33)		(155)				(190)		—		(190)
Noncontrolling interests, net	Noncontrolling interests, net	—		—		—		—		—		(152)		(152)		Noncontrolling interests, net	—		—		—		—		—		(152)		(152)
Balance at June 30, 2022	Balance at June 30, 2022	$	310	$	6,236	$	1,075	$	(485)	$	7,136	$	622	$	7,758	Balance at June 30, 2022	$	310	$	6,236	$	1,075	$	(485)	$	7,136	$	622	$	7,758
For the Six Months Ended June 30, 2021
Balance at January 1, 2021		$	307	$	5,684	$	130	$	(755)	5,366		$	969	$	6,335
Net income (loss)		—		—		179		—		179		170		349
Other comprehensive income (loss)		—		—		—		(81)		(81)		—		(81)
Share-based compensation		3		119		—		—		122		—		122
Dividends on common stock		—		—		(154)		—		(154)		—		(154)
Sale of Class A shares of Hess Midstream LP		—		56		—		—		56		41		97
Noncontrolling interests, net		—		—		—		—		—		(136)		(136)
Balance at June 30, 2021		$	310	$	5,859	$	155	$	(836)	$	5,488	$	1,044	$	6,532

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 June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, the consolidated results of operations for the three and six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, and consolidated cash flows for the six months ended June 30, ~~2022~~2023 and ~~2021.~~2022. 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, ~~2021.~~2022.

2. Inventories

Inventories consisted of the following:


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022

		(In millions)					(In millions)
Crude oil and natural gas liquids	Crude oil and natural gas liquids	$	142	$	52	Crude oil and natural gas liquids	$	84	$	63
Materials and supplies	Materials and supplies	175		171		Materials and supplies	194		154
Total Inventories	Total Inventories	$	317	$	223	Total Inventories	$	278	$	217

3. Property, Plant and Equipment

Capitalized Exploratory Well Costs:

The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the six months ended June 30, ~~2022~~2023 (in millions):


Balance at January 1, ~~2022~~2023	$	~~681~~886
Additions to capitalized exploratory well costs pending the determination of proved reserves	~~194~~128
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	~~(93)~~(78)
Capitalized exploratory well costs charged to expense	(6)
Balance at June 30, ~~2022~~2023	$	~~782~~930

~~Additions~~In the first six months, additions to capitalized exploratory well costs pending determination of proved reserves ~~are~~primarily related to wells drilled on the Stabroek Block (Hess 30%), offshore Guyana, and ~~drilling at~~ the ~~Huron prospect~~Pickerel-1 exploration well (Hess ~~40%~~100%) in the Gulf of ~~Mexico.~~Mexico on Mississippi Canyon Block 727. Reclassifications to wells, facilities and equipment based on the determination of proved reserves resulted from the sanction of the ~~Yellowtail~~Uaru Field development project, the ~~fourth~~fifth sanctioned project on the Stabroek Block. At June 30, 2023, 32 exploration and appraisal wells on the Stabroek Block, with a total cost of $738 million, were capitalized pending determination of proved reserves. The preceding table excludes well costs of $87 million that were incurred and expensed during the first six months of 2023.

At June 30, ~~2022,~~2023, exploratory well costs capitalized for greater than one year following completion of drilling of ~~$417~~$653 million was comprised of the following:

Guyana: Approximately ~~89%~~85% of the capitalized well costs in excess of one year relate to successful exploration wells where hydrocarbons were encountered on the Stabroek Block. The operator also plans further appraisal drilling on the ~~Block~~block and is conducting pre-development planning for additional phases of development.

~~Joint Development Area (JDA)~~U.S.: Approximately 9%8% of the capitalized well costs in excess of one year ~~relates~~relate to the Huron-1 exploration well (Hess 40%) located on Green Canyon Block 69 in the Gulf of Mexico, where oil bearing reservoirs were encountered. Well results are being evaluated and planning for appraisal activities is underway.

Joint Development Area (JDA): Approximately 6% of the capitalized well costs in excess of one year relate to the JDA (Hess 50%) in the Gulf of Thailand, where hydrocarbons were encountered in 3three 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

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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

Malaysia: Approximately 2%1% 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 1one successful exploration well. ~~Subsurface evaluation and pre-development~~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

At June 30, ~~2022,~~2023, Hess Midstream LP (Hess Midstream), a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling ~~$3,078~~$3,201 million (December 31, ~~2021: $2,694~~2022: $3,027 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream assets available to settle the obligations of Hess Midstream included cash and cash equivalents totaling $2$3 million (December 31, ~~2021: $2~~2022: $3 million), property, plant and equipment with a carrying value of ~~$3,145~~$3,188 million (December 31, ~~2021: $3,125~~2022: $3,173 million) and an equity-method investment in the Little Missouri 4 (LM4) gas processing plant of ~~$97~~$93 million (December 31, ~~2021: $102~~2022: $94 million). Hess Corporation owns an approximate 38% interest in Hess Midstream LP, on a consolidated basis, at June 30, 2023.

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 and six months ended June 30, ~~2022~~2023 were $6 million and $11 million respectively, compared with $4 million and $9 ~~million, respectively, compared with $7 million and $14~~ million for the three and six months ended June 30, ~~2021,~~2022, respectively.

In June 2023, Hess Midstream Operations LP (HESM Opco), a consolidated subsidiary of Hess Midstream LP, repurchased approximately 3.4 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of Global Infrastructure Partners (GIP) for $100 million, which was financed by HESM Opco's revolving credit facility. The transaction resulted in an increase in Capital in excess of par and a decrease in Noncontrolling interests of $11 million, and an increase in deferred tax assets and Noncontrolling interests of $6 million resulting from a change in the difference between the carrying value and tax basis of Hess Midstream LP's investment in HESM Opco. The $50 million paid to GIP reduced Noncontrolling interests.

In May 2023, Hess Midstream LP completed an underwritten public equity offering of approximately 12.8 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of GIP. We received net proceeds of $167 million from the public offering. The transaction resulted in an increase in Capital in excess of par and Noncontrolling interests of $158 million and $93 million, respectively. The increase to Noncontrolling interests of $93 million is comprised of $9 million resulting from the change in ownership interest and $84 million from an increase to deferred tax assets resulting from a change in the difference between the carrying value and tax basis of Hess Midstream LP's investment in HESM Opco.

In March 2023, HESM Opco repurchased approximately 3.6 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP for $100 million, which was financed by HESM Opco's revolving credit facility. The transaction resulted in an increase in Capital in excess of par and a decrease in Noncontrolling interests of $8 million, and an increase in deferred tax assets and Noncontrolling interests of $4 million resulting from a change in the difference between the carrying value and tax basis of Hess Midstream LP's investment in HESM Opco. The $50 million paid to GIP reduced Noncontrolling interests.

In April 2022, Hess Midstream LP completed an underwritten public equity offering of approximately 10.2 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of ~~Global Infrastructure Partners (GIP).~~GIP. We received net proceeds of $146 million from the public offering. The transaction resulted in an increase in Capital in excess of par and Noncontrolling interests of $130 million and $88 million, respectively. The increase to Noncontrolling interestsof $88 million is comprised of $16 million resulting from the change in ownership interest and $72 million from an increase to deferred tax assets resulting from a change in the ~~temporary~~ difference between the carrying ~~amount~~value and tax basis of Hess Midstream LP's investment in ~~Hess Midstream Operations LP (HESM Opco).~~HESM Opco.

Concurrent with the April 2022 public offering, HESM Opco ~~a consolidated subsidiary of Hess Midstream LP,~~ repurchased approximately 13.6 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP for $400 million. HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase. The transaction resulted in an increase in Capital in excess of parand a decrease in Noncontrolling interests of $32 million, and an increase in deferred tax assets and Noncontrolling interestsof $17 million resulting from a change in the ~~temporary~~ difference between the carrying ~~amount~~value and tax basis of Hess Midstream LP's investment in HESM Opco. The $200 million paid to GIP reduced Noncontrolling ~~Interests~~interests. ~~We owned an approximate 41% interest in Hess Midstream LP, on a consolidated basis, at June 30, 2022.~~

In March 2021, Hess Midstream LP completed an underwritten public equity offering of 6.9 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of GIP. We received net proceeds of $70 million from the public offering. The transaction resulted in an increase in ~~Capital in excess of par~~ ~~and~~ ~~Noncontrolling interests~~ ~~of $56 million and $41 million, respectively. The increase to~~ ~~Noncontrolling interests~~ of $41 million is comprised of $14 million resulting from the change in ownership interest and $27 million from an increase to deferred tax assets resulting from a change in the temporary difference between the carrying amount and tax basis of Hess Midstream LP's investment in HESM Opco.

~~5. Accrued Liabilities~~

~~Accrued Liabilities consisted of the following:~~

June 30,
2022 December 31,
2021
(In millions)
Accrued operating and marketing expenditures $ 508 $ 462
Accrued capital expenditures 515 479
Accrued payments to royalty and working interest owners 263 253
Current portion of asset retirement obligations 232 185
Accrued interest on debt 143 138
Accrued compensation and benefits 62 124
Other accruals 18 69
Total Accrued Liabilities $ 1,741 $ 1,710

~~6. Debt~~

In April 2022, HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase of approximately

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

~~13.6 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP. The covenants~~5. Accrued Liabilities

Accrued Liabilities consisted of the ~~5.500% fixed-rate senior unsecured notes are substantially similar to the terms of the other existing HESM Opco fixed-rate senior unsecured notes.~~following:

~~In February 2022, we repaid the remaining $500 million outstanding under our $1.0 billion term loan previously scheduled to mature in March 2023.~~


	June 30, 2023		December 31, 2022

	(In millions)
Accrued capital expenditures	$	589	$	499
Accrued operating and marketing expenditures	400		522
Current portion of asset retirement obligations	241		207
Accrued payments to royalty and working interest owners	179		201
Accrued interest on debt	144		143
Accrued compensation and benefits	76		132
Other accruals	125		136
Total Accrued Liabilities	$	1,754	$	1,840

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

6. Revenue

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


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

Three Months Ended June 30, 2022
Sales of our net production volumes:
Three Months Ended June 30, 2023																		Three Months Ended June 30, 2023
Sales of net production volumes:																		Sales of net production volumes:
Crude oil revenue	Crude oil revenue	$	895	$	681	$	37	$	170	$	1,783	$	—	$	—	$	1,783	Crude oil revenue	$	710	$	787	$	24	$	—	$	1,521	$	—	$	—	$	1,521
Natural gas liquids revenue	Natural gas liquids revenue	173		—		—		—		173		—		—		173		Natural gas liquids revenue	112		—		—		—		112		—		—		112
Natural gas revenue	Natural gas revenue	126		—		215		5		346		—		—		346		Natural gas revenue	38		—		182		—		220		—		—		220
Sales of purchased oil and gas	Sales of purchased oil and gas	761		18		—		36		815		—		—		815		Sales of purchased oil and gas	469		15		—		—		484		—		—		484
Intercompany revenue	Intercompany revenue	—		—		—		—		—		314		(314)		—		Intercompany revenue	—		—		—		—		—		322		(322)		—
Total revenues from contracts with customers		1,955		699		252		211		3,117		314		(314)		3,117
Other operating revenues (b)		(95)		(52)		—		(15)		(162)		—		—		(162)
Total sales (b)																		Total sales (b)	1,329		802		206		—		2,337		322		(322)		2,337
Other operating revenues (c)																		Other operating revenues (c)	(30)		(20)		—		—		(50)		2		—		(48)
Total sales and other operating revenues	Total sales and other operating revenues	$	1,860	$	647	$	252	$	196	$	2,955	$	314	$	(314)	$	2,955	Total sales and other operating revenues	$	1,299	$	782	$	206	$	—	$	2,287	$	324	$	(322)	$	2,289
Three Months Ended June 30, 2021
Sales of our net production volumes:
Three Months Ended June 30, 2022																		Three Months Ended June 30, 2022
Sales of net production volumes:																		Sales of net production volumes:
Crude oil revenue	Crude oil revenue	$	661	$	134	$	27	$	135	$	957	$	—	$	—	$	957	Crude oil revenue	$	895	$	681	$	37	$	170	$	1,783	$	—	$	—	$	1,783
Natural gas liquids revenue	Natural gas liquids revenue	120		—		—		—		120		—		—		120		Natural gas liquids revenue	173		—		—		—		173		—		—		173
Natural gas revenue	Natural gas revenue	61		—		178		1		240		—		—		240		Natural gas revenue	126		—		215		5		346		—		—		346
Sales of purchased oil and gas	Sales of purchased oil and gas	299		4		—		26		329		—		—		329		Sales of purchased oil and gas	761		18		—		36		815		—		—		815
Intercompany revenue	Intercompany revenue	—		—		—		—		—		294		(294)		—		Intercompany revenue	—		—		—		—		—		314		(314)		—
Total revenues from contracts with customers		1,141		138		205		162		1,646		294		(294)		1,646
Other operating revenues (b)		(53)		(6)		—		(8)		(67)		—		—		(67)
Total sales (b)																		Total sales (b)	1,955		699		252		211		3,117		314		(314)		3,117
Other operating revenues (c)																		Other operating revenues (c)	(95)		(52)		—		(15)		(162)		—		—		(162)
Total sales and other operating revenues	Total sales and other operating revenues	$	1,088	$	132	$	205	$	154	$	1,579	$	294	$	(294)	$	1,579	Total sales and other operating revenues	$	1,860	$	647	$	252	$	196	$	2,955	$	314	$	(314)	$	2,955
Six Months Ended June 30, 2022
Sales of our net production volumes:
Six Months Ended June 30, 2023																		Six Months Ended June 30, 2023
Sales of net production volumes:																		Sales of net production volumes:
Crude oil revenue	Crude oil revenue	$	1,731	$	907	$	68	$	316	$	3,022	$	—	$	—	$	3,022	Crude oil revenue	$	1,379	$	1,612	$	53	$	—	$	3,044	$	—	$	—	$	3,044
Natural gas liquids revenue	Natural gas liquids revenue	354		—		—		—		354		—		—		354		Natural gas liquids revenue	253		—		—		—		253		—		—		253
Natural gas revenue	Natural gas revenue	211		—		405		10		626		—		—		626		Natural gas revenue	92		—		362		—		454		—		—		454
Sales of purchased oil and gas	Sales of purchased oil and gas	1,421		22		—		71		1,514		—		—		1,514		Sales of purchased oil and gas	996		32		—		—		1,028		—		—		1,028
Intercompany revenue	Intercompany revenue	—		—		—		—		—		626		(626)		—		Intercompany revenue	—		—		—		—		—		625		(625)		—
Total revenues from contracts with customers		3,717		929		473		397		5,516		626		(626)		5,516
Other operating revenues (b)		(153)		(67)		—		(28)		(248)		—		—		(248)
Total sales (b)																		Total sales (b)	2,720		1,644		415		—		4,779		625		(625)		4,779
Other operating revenues (c)																		Other operating revenues (c)	(56)		(27)		—		—		(83)		4		—		(79)
Total sales and other operating revenues	Total sales and other operating revenues	$	3,564	$	862	$	473	$	369	$	5,268	$	626	$	(626)	$	5,268	Total sales and other operating revenues	$	2,664	$	1,617	$	415	$	—	$	4,696	$	629	$	(625)	$	4,700
Six Months Ended June 30, 2021
Sales of our net production volumes:
Six Months Ended June 30, 2022																		Six Months Ended June 30, 2022
Sales of net production volumes:																		Sales of net production volumes:
Crude oil revenue	Crude oil revenue	$	1,546	$	315	$	49	$	251	$	2,161	$	—	$	—	$	2,161	Crude oil revenue	$	1,731	$	907	$	68	$	316	$	3,022	$	—	$	—	$	3,022
Natural gas liquids revenue	Natural gas liquids revenue	263		—		—		—		263		—		—		263		Natural gas liquids revenue	354		—		—		—		354		—		—		354
Natural gas revenue	Natural gas revenue	174		—		341		4		519		—		—		519		Natural gas revenue	211		—		405		10		626		—		—		626
Sales of purchased oil and gas	Sales of purchased oil and gas	597		8		—		45		650		—		—		650		Sales of purchased oil and gas	1,421		22		—		71		1,514		—		—		1,514
Intercompany revenue	Intercompany revenue	—		—		—		—		—		583		(583)		—		Intercompany revenue	—		—		—		—		—		626		(626)		—
Total revenues from contracts with customers		2,580		323		390		300		3,593		583		(583)		3,593
Other operating revenues (b)		(94)		(10)		—		(12)		(116)		—		—		(116)
Total sales (b)																		Total sales (b)	3,717		929		473		397		5,516		626		(626)		5,516
Other operating revenues (c)																		Other operating revenues (c)	(153)		(67)		—		(28)		(248)		—		—		(248)
Total sales and other operating revenues	Total sales and other operating revenues	$	2,486	$	313	$	390	$	288	$	3,477	$	583	$	(583)	$	3,477	Total sales and other operating revenues	$	3,564	$	862	$	473	$	369	$	5,268	$	626	$	(626)	$	5,268

(a)Other includes our interest in the Waha Concession in Libya, ~~and our interests in Denmark,~~ which ~~were~~was sold in ~~the third quarter of 2021.~~November 2022.

(b)~~Includes~~Guyana crude oil revenue includes $88 million and $196 million of revenue from non-customers for the three and six months ended June 30, 2023, respectively. There was no revenue from non-customers for the three and six months ended June 30, 2022.

(c)Other operating revenues are not a component of revenues from contracts with customers, and primarily includes gains (losses) on commodity derivatives.

There have been no significant changes to contracts with customers or the composition thereof during the six months ended

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

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

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

June 30, ~~2022.~~2023. 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 June 30, ~~2022,~~2023, contract liabilities of ~~$24~~$27 million (December 31, ~~2021:~~2022: $24 million) ~~resulted from~~were primarily due to 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 June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, there were no contract assets.

~~8. Impairment and Other~~

In June 2021, the U.S. Bankruptcy Court approved the bankruptcy plan for Fieldwood Energy LLC (Fieldwood) which includes transferring abandonment obligations of Fieldwood to predecessors in title of certain of its assets, who are jointly and severally liable for the obligations. Second quarter 2021 results include a charge of $147 million ($147 million after income taxes) in connection with abandonment obligations in the West Delta 79/86 Field (West Delta Field), which we sold to a Fieldwood predecessor in 2004.

~~9. Retirement Plans~~

~~Components of net periodic benefit cost consisted of the following:~~

Three Months Ended
June 30, Six Months Ended
June 30,
2022 2021 2022 2021
(In millions)

Service cost $ 12 $ 13 $ 25 $ 27
Interest cost (a) 17 14 33 28
Expected return on plan assets (a) (52) (49) (105) (99)
Amortization of unrecognized net actuarial losses (a) 3 13 6 28
Settlement loss (a) 2 3 2 4
Net periodic benefit cost (income) (a) $ (18) $ (6) $ (39) $ (12)

(a) Net non-service cost included in Other, net in the Statement of Consolidated Income for the three and six months ended June 30, 2022 was income of $30 million and $64 million, respectively, compared with income of $19 million and $39 million for the three and six months ended June 30, 2021.

In the second quarter of 2022, the Hess Corporation Employees’ Pension Plan purchased a single premium annuity contract at a cost of approximately $170 million using assets of the plan to settle and transfer certain of its obligations to a third party. This partial settlement resulted in a noncash charge of $13 million to recognize unamortized actuarial losses. In connection with this settlement transaction, as required under U.S. accounting standards, we remeasured the funded status of the plan, which increased by $154 million primarily due to a change in the weighted average discount rate used to value the projected benefit obligation, and an update to the fair value of plan assets. The change in the funded status is reflected in ~~Post-retirement benefit assets~~ ~~in the~~ ~~Consolidated Balance Sheet~~.

In the second quarter of 2022, the HOVENSA Legacy Employees' Pension Plan paid lump sums of approximately $20 million to certain participants, and purchased a single premium annuity contract at a cost of approximately $80 million, to settle the plan's projected benefit obligation. The settlement transactions resulted in a noncash gain of $11 million to recognize unamortized actuarial gains. In connection with these settlement transactions, as required under U.S. accounting standards, we remeasured the funded status of the plan, which increased by $6 million. The change in the funded status is reflected in ~~Post-retirement benefit assets~~ ~~in the~~ ~~Consolidated Balance Sheet~~.

For the full year 2022, we forecast service cost for our pension and postretirement medical plans to be approximately $45 million and net non-service cost to be approximately $118 million of income, which is comprised of expected return on plan assets of approximately $200 million, interest cost of approximately $70 million, amortization of unrecognized net actuarial losses of approximately $10 million, and net settlement losses of $2 million. In 2022, we expect to contribute approximately $45 million to our funded pension plans.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

~~10.~~7. Impairment and Other

In the second quarter of 2023, we recognized a pre-tax charge of $82 million ($82 million after income taxes) that resulted from revisions to estimated costs to abandon certain wells, pipelines and production facilities in the West Delta Field in the Gulf of Mexico. These abandonment obligations were assigned to us as a former owner after they were discharged from Fieldwood Energy LLC as part of its approved bankruptcy plan in 2021.

8. Retirement Plans

Components of net periodic benefit cost consisted of the following:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022

	(In millions)

Service cost	$	10	$	12	$	19	$	25
Interest cost (a)	25		17		50		33
Expected return on plan assets (a)	(40)		(52)		(79)		(105)
Amortization of unrecognized net actuarial losses (a)	1		3		1		6
Settlement loss (a)	—		2		$	—	$	2
Net periodic benefit cost (income) (a)	$	(4)	$	(18)	$	(9)	$	(39)

(a) Net non-service cost, which is included in Other, net in the Statement of Consolidated Income, was income of $14 million and $28 million for the three and six months ended June 30, 2023, respectively, compared with income of $30 million and $64 million for the three and six months ended June 30, 2022.

In the second quarter of 2022, the Hess Corporation Employees’ Pension Plan purchased a single premium annuity contract at a cost of $166 million using assets of the plan to settle and transfer certain of its obligations to a third party. This partial settlement resulted in a noncash settlement loss of $13 million to recognize unamortized actuarial losses.

In the second quarter of 2022, the HOVENSA Legacy Employees' Pension Plan paid lump sums to certain participants totaling $20 million, and purchased a single premium annuity contract at a cost of $80 million, to settle the plan's projected benefit obligation in connection with terminating the plan. The settlement transactions resulted in a noncash settlement gain of $11 million to recognize unamortized actuarial gains. The assets remaining after settlement of the plan's projected benefit obligation of $15 million were transferred to the Hess Corporation Employees' Pension Plan in December 2022.

In 2023, we expect to contribute approximately $2 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 June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In millions)									(In millions)
Net income (loss) attributable to Hess Corporation:
Net income (loss)		$	754	$	13	$	1,259	$	349
Less: Net income (loss) attributable to noncontrolling interests		87		86		175		170
Net income (loss) attributable to Hess Corporation		$	667	$	(73)	$	1,084	$	179
Net income attributable to Hess Corporation:										Net income attributable to Hess Corporation:
Net income										Net income	$	205	$	754	$	633	$	1,259
Less: Net income attributable to noncontrolling interests										Less: Net income attributable to noncontrolling interests	86		87		168		175
Net income attributable to Hess Corporation										Net income attributable to Hess Corporation	$	119	$	667	$	465	$	1,084
Weighted average number of common shares outstanding:	Weighted average number of common shares outstanding:									Weighted average number of common shares outstanding:
Basic	Basic	309.7		307.5		309.3		306.7		Basic	306.0		309.7		305.7		309.3
Effect of dilutive securities	Effect of dilutive securities									Effect of dilutive securities
Restricted common stock	Restricted common stock	0.6		—		0.6		0.7		Restricted common stock	0.3		0.6		0.5		0.6
Stock options	Stock options	0.6		—		0.6		0.5		Stock options	0.7		0.6		0.7		0.6
Performance share units	Performance share units	—		—		0.1		0.8		Performance share units	0.5		—		0.5		0.1
Diluted	Diluted	310.9		307.5		310.6		308.7		Diluted	307.5		310.9		307.4		310.6

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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


		Three Months Ended June 30,		Six Months Ended June 30,			Three Months Ended June 30,		Six Months Ended June 30,
		2022	2021	2022	2021		2023	2022	2023	2022
Restricted common stock	Restricted common stock	—	1,641,860	48	94,726	Restricted common stock	1,789	—	61,489	48
Stock options	Stock options	269,748	2,562,983	172,581	832,454	Stock options	189,479	269,748	121,226	172,581
Performance share units	Performance share units	29,668	1,161,324	30,510	39,608	Performance share units	—	29,668	—	30,510

During the six months ended June 30, ~~2022,~~2023, we granted ~~565,318~~451,226 shares of restricted stock ~~(2021: 705,489)~~(2022: 565,318), ~~178,008~~130,272 performance share units ~~(2021: 205,155)~~(2022: 178,008) and ~~269,748~~189,479 stock options ~~(2021: 319,295)~~(2022: 269,748).

At December 31, 2021, the remaining amount under our Board authorized $7.5 billion stock repurchase plan was $650 million. In the second quarter of 2022, we repurchased approximately 1.8 million shares of common stock for $190 million. No shares of common stock were repurchased during 2021.

~~11.~~ 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 United States 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 2two remaining active cases, filed by Pennsylvania 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 December 2017, the State of Maryland filed a lawsuit alleging that we and other major oil companies damaged the groundwater in

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

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

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

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

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

In March 2014, we received an Administrative Order from the EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York. Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected shipbuilding and repair facility adjacent to the Canal. The remedy selected by the EPA includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap. The EPA’s original estimate was that this remedy would cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain. We have complied with the EPA’s March 2014 Administrative Order and contributed funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert. In January 2020, we received an additional Administrative Order from the EPA requiring us and several other parties to begin Remedial Action along the uppermost portion of the Canal. We intend to comply with this Administrative Order. The remediation work began in the fourth quarter of 2020. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us, and the costs will continue to be allocated amongst the parties, as they were for the Remedial Design.

From time to time, we are involved in other judicial and administrative proceedings relating to environmental matters. We periodically receive notices from the EPA that we are a “potential responsible party” under the Superfund legislation with respect to various waste disposal sites. Under this legislation, all potentially responsible parties may be jointly and severally liable. For any site for which we have received such a notice, the EPA’s claims or assertions of liability against us relating to these sites have not been fully developed, or the EPA’s claims have been settled or a settlement is under consideration, in all cases for amounts that are not material. Beginning in 2017, certain states, municipalities and private associations in California, Delaware, Maryland, Rhode Island and South Carolina separately filed lawsuits against oil, gas and coal producers, including us, for alleged damages purportedly caused by climate change. These proceedings include claims for monetary damages and injunctive relief. Beginning in 2013, various parishes in Louisiana filed suit against approximately 100 oil and gas companies, including us, alleging that the companies’ operations and activities in certain fields violated the State and Local Coastal Resource Management Act of 1978, as amended, and caused

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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. On April 28, 2022, HONX, Inc. ~~has~~ initiated a Chapter 11 § 524G process in the United States Bankruptcy Court for the Southern District of Texas, Houston Division, to resolve these asbestos-related claims. ~~While~~In February 2023, Hess, HONX, Inc., the ~~ultimate outcome~~Unsecured Creditors’ Committee, and ~~impact to us cannot be predicted with certainty, we believe that the~~counsel representing claimants, reached a mediated resolution of ~~these proceedings will not~~the matter, contingent upon final approvals of all parties and confirmation by the Bankruptcy Court. As of June 30, 2023, we have a ~~material adverse effect~~provision of $116 million for the amounts expected to be funded to the § 524G trust established for the settlement of claims, based on ~~our consolidated financial position, results of operations or cash flows.~~the mediated resolution.

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,

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

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

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

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.

PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

~~12.~~11. Segment Information

We currently have 2two operating segments, Exploration and Production and Midstream. All unallocated costs are reflected under Corporate, Interest and Other. The following table presents operating segment financial data:

Exploration and Production Midstream Corporate, Interest and Other Eliminations Total
(In millions)
For the Three Months Ended June 30, 2022
Sales and Other Operating Revenues - Third parties $ 2,955 $ — $ — $ — $ 2,955
Intersegment Revenues — 314 — (314) —
Sales and Other Operating Revenues $ 2,955 $ 314 $ — $ (314) $ 2,955
Net Income (Loss) attributable to Hess Corporation $ 723 $ 65 $ (121) $ — $ 667
Depreciation, Depletion and Amortization 345 44 2 — 391
Provision (Benefit) for Income Taxes 321 7 — — 328
Capital Expenditures 593 72 — — 665
For the Three Months Ended June 30, 2021
Sales and Other Operating Revenues - Third parties $ 1,579 $ — $ — $ — $ 1,579
Intersegment Revenues — 294 — (294) —
Sales and Other Operating Revenues $ 1,579 $ 294 $ — $ (294) $ 1,579
Net Income (Loss) attributable to Hess Corporation $ (25) $ 76 $ (124) $ — $ (73)
Depreciation, Depletion and Amortization 344 41 — — 385
Impairment and other 147 — — — 147
Provision (Benefit) for Income Taxes 119 3 — — 122
Capital Expenditures 396 47 — — 443
For the Six Months Ended June 30, 2022
Sales and Other Operating Revenues - Third parties $ 5,268 $ — $ — $ — $ 5,268
Intersegment Revenues — 626 — (626) —
Sales and Other Operating Revenues $ 5,268 $ 626 $ — $ (626) $ 5,268
Net Income (Loss) attributable to Hess Corporation $ 1,183 $ 137 $ (236) $ — $ 1,084
Depreciation, Depletion and Amortization 637 89 2 — 728
Provision (Benefit) for Income Taxes 513 12 — — 525
Capital Expenditures 1,136 109 — — 1,245
For the Six Months Ended June 30, 2021
Sales and Other Operating Revenues - Third parties $ 3,477 $ — $ — $ — $ 3,477
Intersegment Revenues — 583 — (583) —
Sales and Other Operating Revenues $ 3,477 $ 583 $ — $ (583) $ 3,477
Net Income (Loss) attributable to Hess Corporation $ 283 $ 151 $ (255) $ — $ 179
Depreciation, Depletion and Amortization 699 81 1 — 781
Impairment and other 147 — — — 147
Provision (Benefit) for Income Taxes 239 6 — — 245
Capital Expenditures 676 70 — — 746


	Exploration and Production		Midstream		Corporate, Interest and Other		Eliminations		Total

	(In millions)
For the Three Months Ended June 30, 2023
Sales and other operating revenues	$	2,287	$	2	$	—	$	—	$	2,289
Intersegment revenues	—		322		—		(322)		—
Total sales and other operating revenues	$	2,287	$	324	$	—	$	(322)	$	2,289

Net income (loss) attributable to Hess Corporation	$	155	$	62	$	(98)	$	—	$	119
Depreciation, depletion and amortization	450		47		—		—		497
Impairment and other	82		—		—		—		82
Provision for income taxes	152		8		—		—		160
Capital expenditures	904		52		—		—		956
For the Three Months Ended June 30, 2022
Sales and other operating revenues	$	2,955	$	—	$	—	$	—	$	2,955
Intersegment revenues	—		314		—		(314)		—
Total sales and other operating revenues	$	2,955	$	314	$	—	$	(314)	$	2,955

Net income (loss) attributable to Hess Corporation	$	723	$	65	$	(121)	$	—	$	667
Depreciation, depletion and amortization	345		44		2		—		391
Provision for income taxes	321		7		—		—		328
Capital expenditures	593		72		—		—		665
For the Six Months Ended June 30, 2023
Sales and other operating revenues	$	4,696	$	4	$	—	$	—	$	4,700
Intersegment revenues	—		625		—		(625)		—
Total sales and other operating revenues	$	4,696	$	629	$	—	$	(625)	$	4,700

Net income (loss) attributable to Hess Corporation	$	560	$	123	$	(218)	$	—	$	465
Depreciation, depletion and amortization	893		94		1		—		988
Impairment and other	82		—		—		—		82
Provision for income taxes	322		14		—		—		336
Capital expenditures	1,639		109		—		—		1,748
For the Six Months Ended June 30, 2022
Sales and other operating revenues	$	5,268	$	—	$	—	$	—	$	5,268
Intersegment revenues	—		626		—		(626)		—
Total sales and other operating revenues	$	5,268	$	626	$	—	$	(626)	$	5,268

Net income (loss) attributable to Hess Corporation	$	1,183	$	137	$	(236)	$	—	$	1,084
Depreciation, depletion and amortization	637		89		2		—		728
Provision for income taxes	513		12		—		—		525
Capital expenditures	1,136		109		—		—		1,245

Corporate, Interest and Other had interest income of $21 million and $41 million for the three and six months ended June 30, 2023, respectively, compared to $3 million for both the three and six months ended June 30, 2022. Interest income is included in

Other, net

in the Statement of Consolidated Income.

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:


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022

		(In millions)					(In millions)
Exploration and Production	Exploration and Production	$	14,886	$	14,173	Exploration and Production	$	15,792	$	15,022
Midstream	Midstream	3,755		3,671		Midstream	3,864		3,775
Corporate, Interest and Other	Corporate, Interest and Other	2,539		2,671		Corporate, Interest and Other	2,574		2,898
Total	Total	$	21,180	$	20,515	Total	$	22,230	$	21,695

~~13.~~12. Financial Risk Management Activities

In the normal course of our business, we are exposed to commodity risks related to changes in the prices of crude oil and natural gas, as well as changes in interest rates and foreign currency values. Financial risk management activities include transactions designed to reduce risk in the selling prices of crude oil or natural gas we produce or ~~by reducing~~reduce 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. 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 June 30, ~~2022,~~2023, these instruments relate to the British Pound 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:


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022

		(In millions)					(In millions)
Commodity - crude oil hedge contracts (millions of barrels)	Commodity - crude oil hedge contracts (millions of barrels)	27.6		54.8		Commodity - crude oil hedge contracts (millions of barrels)	23.9		—

Foreign exchange forwards		$	157	$	145
Foreign exchange forwards / swaps						Foreign exchange forwards / swaps	$	236	$	177
Interest rate swaps	Interest rate swaps	$	100	$	100	Interest rate swaps	$	100	$	100

~~At December 31, 2021,~~In the first quarter of 2023, we ~~had~~ hedged ~~90,000~~80,000 barrels of oil per day (bopd) with WTI ~~collars~~put options with an average monthly floor price of ~~$60~~$70 per barrel, and ~~an average monthly ceiling price of $100 per barrel and 60,000~~50,000 bopd with Brent ~~collars~~put options with an average monthly floor price of ~~$65 per barrel and an average monthly ceiling price of $105~~$75 per barrel, for ~~calendar 2022. In~~ the ~~first quarter~~remainder of ~~2022, we purchased WTI and Brent call options to remove~~2023.

The table below reflects the ceiling price on our price collars for the period April 1, 2022 through December 31, 2022 for $325 million. As a result, during this period, we are able to realize WTI and Brent selling prices above $100 per barrel and $105 per barrel, respectively, to the extent that market prices exceed these thresholds. The WTI $60 per barrel put options for 90,000 bopd and the Brent $65 per barrel put options for 60,000 bopd in our price collars remain outstanding through December 31, 2022.fair values of risk management derivative instruments.


	Assets		Liabilities

	(In millions)
June 30, 2023
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options	$	100	$	—
Interest rate swaps	—		(3)
Total derivative contracts designated as hedging instruments	100		(3)
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	100		(3)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	100	$	(3)
December 31, 2022
Derivative Contracts Designated as Hedging Instruments:
Interest rate swaps	$	—	$	(4)
Total derivative contracts designated as hedging instruments	—		(4)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards and swaps	—		(2)
Total derivative contracts not designated as hedging instruments	—		(2)
Gross fair value of derivative contracts	—		(6)
Gross amounts offset in the Consolidated Balance Sheet	—		—
Net Amounts Presented in the Consolidated Balance Sheet	$	—	$	(6)

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)
June 30, 2022
Derivative Contracts Designated as Hedging Instruments:
Crude oil put options $ 26 $ —
Interest rate swaps — (3)
Total derivative contracts designated as hedging instruments 26 (3)
Derivative Contracts Not Designated as Hedging Instruments:
Foreign exchange forwards and swaps 5 —
Total derivative contracts not designated as hedging instruments 5 —
Gross fair value of derivative contracts 31 (3)
Gross amounts offset in the Consolidated Balance Sheet — —
Net Amounts Presented in the Consolidated Balance Sheet $ 31 $ (3)
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 June 30, 2022 and December 31, 2021, the~~ fair value of our crude oil hedge contracts is presented within Other current assets~~in our~~ ~~Consolidated Balance Sheet. The fair value of our foreign exchange forwards and swaps is presented within~~ ~~Other current assets~~ ~~at June 30, 2022 and within~~ ~~Accrued liabilities~~ ~~at December 31, 2021~~ in our Consolidated Balance Sheet. The fair value of our interest rate swaps is presented within Other liabilities and deferred credits ~~at June 30, 2022~~in our Consolidated Balance Sheet. The fair value of our foreign exchange forwards and swaps is presented within~~Other assets~~ ~~at December 31, 2021~~Accrued liabilities in our Consolidated Balance Sheet. All fair values in the table above are based on Level 2 inputs.

Derivative contracts designated as hedging instruments:

Crude oil derivatives designated as cash flow hedges: Crude oil hedging contracts decreased Sales and other operating revenues by ~~$163~~$52 million and ~~$255~~$86 million in the three and six months ended June 30, ~~2022,~~2023, respectively. In the three and six months ended June 30, ~~2021,~~2022, crude oil hedging contracts decreased Sales and other operating revenues by ~~$64~~$163 million and ~~$115~~$255 million, respectively. At June 30, ~~2022,~~2023, pre-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding crude oil hedging contracts were ~~$306~~$4 million ($~~306~~4 million after income taxes), all of which will be reclassified into earnings during the remainder of ~~2022~~2023 as the hedged crude oil sales are recognized in earnings.

~~Interest rate swaps designated as fair value hedges:~~ We had interest rate swaps with gross notional amounts totaling $100 million at June 30, 2022 and 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 and six months ended June 30, 2022, the change in fair value of interest rate swaps was a decrease of $1 million and $5 million, respectively, compared with a decrease of nil and $1 million in the three and six months ended June 30, 2021, respectively, with a corresponding adjustment in the carrying value of the hedged fixed-rate debt.

Derivative contracts not designated as hedging instruments:

Foreign exchange: Foreign exchange gains and losses, which are reported in Other, net in Revenues and non-operating income in the Statement of Consolidated Income, were losses of $2 million and nil in the three and six months ended June 30, 2023, respectively, compared with losses of $3 million in both the three and six months ended June 30, ~~2022, compared with losses of $1 million and $2 million in the three and six months ended June 30, 2021, respectively.~~2022. A component of foreign exchange gains and losses is the result of foreign exchange derivative contracts that are not designated as hedges, which amounted to net losses of nil and $2 million in the three and six months ended June 30, 2023, respectively, compared with net gains of $10 million and $14 million in the three and six months ended June 30, 2022, ~~respectively, compared with net gains of $1 million and nil in the three and six months ended June 30, 2021,~~ respectively.

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

~~HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES~~

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

Fair Value Measurement:

At June 30, ~~2022,~~2023, our total long-term debt, which was substantially comprised of fixed-rate debt instruments, had a carrying value of ~~$8,332~~$8,467 million and a fair value of ~~$8,297~~$8,374 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 June 30, ~~2022~~2023 and December 31, ~~2021.~~

~~14. Subsequent Events~~

In July 2022, Hess Corporation replaced its $3.5 billion revolving credit facility expiring in May 2024 with a new $3.25 billion revolving credit facility maturing in July 2027. Borrowings on the facility will bear interest based on the Secured Overnight Financing Rate (SOFR), plus the applicable margins specified in the credit agreement, which generally vary based on the credit rating of the Corporation's senior, unsecured, non-credit enhanced long-term debt. The new credit agreement has substantially similar terms to the prior agreement, including covenants.

In July 2022, HESM Opco amended and restated its credit agreement for its $1.4 billion senior secured syndicated credit facilities, consisting of a $1.0 billion revolving credit facility and a fully drawn $400 million term loan. The amended and restated credit agreement, among other things, extended the maturity date from December 2024 to July 2027, increased the accordion feature to up to an additional $750 million, which does not represent a lending commitment from the lenders, and replaced the London Interbank Offered Rate (LIBOR) as the benchmark interest rate with SOFR. The amended and restated credit agreement has substantially similar terms to the prior agreement, including commitment amounts, guarantees, secured collateral and covenants.2022.

1716

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 June 30, ~~2022~~2023 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, ~~2021.~~2022. 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, ~~2021.~~2022.

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 in the United States, Guyana, the Malaysia/Thailand Joint Development Area (JDA)~~, Malaysia,~~ and ~~Libya.~~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 discovered a significant resource base and are executing a multi-phased development of the Block. The Liza Phase 1 development reached its new production capacity of more than 140,000 gross bopd in June 2022 following the completion of production optimization work. The Liza Phase 2 development achieved first production in February 2022 and reached its production capacity of approximately 220,000 gross bopd in July. A third development, Payara, was sanctioned in the third quarter of 2020 and is expected to achieve first production in late 2023 with production capacity of approximately 220,000 gross bopd. A fourth development, Yellowtail, was sanctioned in April 2022 and is expected to achieve first production in 2025, with production capacity of approximately 250,000 gross bopd.block. We currently plan to have ~~at least~~ six floating production, storage and offloading vessels (FPSO) with an aggregate expected production capacity of more than 11.2 million gross bopd on the Stabroek Block inby the end of 2027, and the potential for up to ten FPSOs to develop the current discovered recoverable resource base.

Our Midstream operating segment, which is comprised of Hess Corporation’s approximate 38% consolidated ownership interest in Hess Midstream LP at June 30, 2023, 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.

2023 Outlook

Our E&P capital and exploratory expenditures are forecast to be approximately $3.7 billion for 2023. Oil and gas net production in 2023 is forecast to be in the range of 385,000 barrels of oil equivalent per day (boepd) to 390,000 boepd. For the remainder of 2023, we have WTI put options for 80,000 bopd with an average monthly floor price of $70 per barrel and Brent put options for 50,000 bopd with an average monthly floor price of $75 per barrel.

Second Quarter Results

In the second quarter of 2023, net income was $119 million, compared with $667 million in the second quarter of 2022. Excluding items affecting comparability of earnings between periods detailed on page 24, adjusted net income was $201 million in the second quarter of 2023. The decrease in adjusted after-tax earnings in the second quarter of 2023 compared with the prior-year quarter was primarily due to lower realized selling prices, partially offset by the net impact of higher production volumes in the second quarter of 2023.

Exploration and Production Results

In the second quarter of 2023, E&P had net income of $155 million, compared with $723 million in the second quarter of 2022. Excluding items affecting comparability of earnings between periods, adjusted net income was $237 million in the second quarter of 2023. Total net production averaged 387,000 boepd in the second quarter 2023, compared with 303,000 boepd, proforma for asset sold, in the second quarter of 2022. The average realized crude oil selling price, including hedging, was $71.13 per barrel in the second quarter of 2023, compared with $99.16 per barrel in the second quarter of 2022. The average realized NGL selling price in the second quarter of 2023 was $17.95 per barrel, compared with $40.92 per barrel in the prior-year quarter, while the average realized natural gas selling price was $3.82 per thousand cubic feet (mcf) in the second quarter of 2023, compared with $6.45 per mcf in the second quarter of 2022.

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

•In North Dakota, net production from the Bakken averaged 181,000 boepd for the second quarter of 2023 (2022 Q2: 140,000 boepd), reflecting increased drilling and completion activity, higher NGL and natural gas volumes received under percentage of proceeds contracts due to lower commodity prices, and higher uptime after weather related shut-ins in the prior-year quarter. NGL and natural gas volumes received under percentage of proceeds contracts were 22,000 boepd in the second quarter of 2023 compared with 7,000 boepd in the second quarter of 2022 due to lower realized NGL and natural gas prices increasing volumes received as consideration for gas processing fees. We drilled 32 wells, completed 28 wells, and brought 30 new wells online during the second quarter of 2023. We forecast net production to be approximately 185,000 boepd for the third quarter and in the range of 175,000 boepd to 180,000 boepd for the full year 2023.

PART I - FINANCIAL INFORMATION (CONT'D.)

Overview (continued)

•In the Gulf of Mexico, net production for the second quarter of 2023 averaged 32,000 boepd (2022 Q2: 29,000 boepd) primarily due to an additional well brought online at the Llano Field.

In July 2023, the Pickerel-1 exploration well (Hess 100%) located in Mississippi Canyon Block 727 was an oil discovery. The well encountered approximately 90 feet of net pay in high quality, oil bearing, Miocene age reservoir. Planning is underway to tie-back the well to the Tubular Bells production facility with first oil expected in mid-2024.

•At the Stabroek Block (Hess 30%), offshore Guyana, net production from the Liza Destiny and Liza Unity FPSOs totaled 110,000 bopd for the second quarter of 2023 (2022 Q2: 67,000 bopd). Net production from Guyana in the second quarter of 2023 included 13,000 bopd of tax barrels (2022 Q2: 0 bopd). The Liza Unity FPSO, which commenced production in February 2022, reached its initial expected production capacity of approximately 220,000 gross bopd in July 2022. The Liza Unity FPSO is expected to increase its production capacity to approximately 250,000 gross bopd by the end of 2023 as a result of production optimization work. In the second quarter of 2023, we sold nine cargos of crude oil from Guyana compared with six cargos in the prior-year quarter. We forecast net production to be approximately 110,000 bopd for the third quarter and approximately 115,000 bopd for the full year 2023, which includes tax barrels of approximately 13,000 bopd and 15,000 bopd, respectively.

The third development, Payara, which will utilize the Prosperity FPSO with a production capacity of approximately 220,000 gross bopd, remains on track for startup early in the fourth quarter. The fourth development, Yellowtail, which will utilize the ONE GUYANA FPSO, was sanctioned in April 2022 with a production capacity of approximately 250,000 gross bopd and first production expected in 2025. The fifth development, Uaru, which will utilize the Errea Wittu FPSO, was sanctioned in April 2023 with a production capacity of approximately 250,000 gross bopd and first production expected in 2026.

The expiration of the exploration license for the Stabroek Block was extended one year from October 2026 to October 2027, and the end of the first renewal period of the exploration license, which requires the relinquishment of 20% of the acreage not held by discoveries, was extended one year from October 2023 to October 2024, both as a result of force majeure due to the COVID-19 pandemic.

•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged 37,000 boepd for the second quarter of 2023 (2022 Q2: 41,000 boepd), including contribution from unitized acreage in Malaysia. Net production from North Malay Basin, offshore Peninsular Malaysia, averaged 27,000 boepd for the second quarter of 2023 (2022 Q2: 26,000 boepd).

•In Canada, offshore Newfoundland (Hess 25%), the operator completed drilling of the Ephesus exploration well in June 2023. The well did not encounter commercial quantities of hydrocarbons and well costs incurred of $36 million were recorded to exploration expense in the second quarter of 2023.

The following is an update of significant Midstream activities:

•In June 2023, HESM Opco, a consolidated subsidiary of Hess Midstream LP, repurchased approximately 3.4 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP for $100 million, financed by HESM Opco's revolving credit facility, of which we received net proceeds of $50 million.

•In May 2023, Hess Midstream LP completed aan underwritten public equity offering of approximately ~~10.2~~12.8 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of GIP. We received net proceeds of ~~$146~~$167 million from the public offering. Concurrent with the public offering, HESM Opco repurchased approximately 13.6 million HESM Opco Class B units from a subsidiary of Hess Corporation and an affiliate of GIP for $400 million, of which we received net proceeds of $200 million. HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase.

After giving effect to these transactions, ~~we own~~Hess Corporation owns an approximate ~~41%~~38% interest in Hess Midstream LP, on a consolidated basis.

~~2022 Highlights and Outlook~~

Following the startup of the Liza Phase 2 project in February 2022, we repaid the remaining $500 million outstanding under our $1.0 billion term loan, and in March 2022, we announced a 50% increase to our quarterly dividend on common stock. In June 2022, we repurchased approximately 1.8 million shares of common stock for $190 million. We intend to utilize the remaining amount authorized under our stock repurchase plan of $460 million by the end of the year. Excluding our Midstream Segment, we ended the second quarter of 2022 with approximately $2.16 billion in cash and cash equivalents.

Oil and gas net production in 2022, excluding Libya, is forecast to be approximately 320,000 barrels of oil equivalent per day (boepd). Our E&P capital and exploratory expenditures for 2022 are forecast to be approximately $2.7 billion. 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.

~~Second Quarter Results~~

In the second quarter of 2022, net income was $667 million, compared with a net loss of $73 million in the second quarter of 2021. Excluding items affecting comparability of earnings between periods detailed on pages 25 and 27, adjusted net income was $74 million in the second quarter of 2021. The improvement in after-tax earnings in the second quarter of 2022 compared with the prior-year quarter adjusted results was primarily due to higher realized selling prices in the second quarter of 2022.

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

~~Exploration and Production Results~~

In the second quarter of 2022, E&P had net income of $723 million compared with a net loss of $25 million in the second quarter of 2021. Excluding items affecting comparability of earnings between periods, adjusted net income was $122 million in the second quarter of 2021. Total net production, excluding Libya, averaged 303,000 boepd in the second quarter 2022, compared with 307,000 boepd in the second quarter of 2021, or 302,000 boepd pro forma for assets sold. The average realized crude oil selling price, including hedging, was $99.16 per barrel in the second quarter of 2022, compared with $59.79 per barrel in the second quarter of 2021. The average realized NGL selling price in the second quarter of 2022 was $40.92 per barrel, compared with $23.12 per barrel in the prior-year quarter, while the average realized natural gas selling price was $6.45 per thousand cubic feet (mcf) in the second quarter of 2022, compared with $4.05 per mcf in the second quarter of 2021.

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

•In North Dakota, net production from the Bakken averaged 140,000 boepd for the second quarter of 2022 (2021 Q2: 159,000 boepd), reflecting unplanned production shut-ins caused by severe weather in April and May. We operated three rigs, drilled 20 wells, completed 19 wells, and brought 19 new wells online during the second quarter of 2022. In July, we added a fourth drilling rig. We forecast net production to be in the range of 155,000 boepd to 160,000 boepd for the third quarter, in the range of 160,000 boepd to 165,000 boepd for the fourth quarter, and in the range of 150,000 boepd to 155,000 boepd for the full year 2022.

•In the Gulf of Mexico, net production for the second quarter of 2022 averaged 29,000 boepd (2021 Q2: 52,000 boepd), primarily due to field decline and unplanned downtime at the Stampede and Penn State fields. We forecast Gulf of Mexico net production to be in the range of 25,000 boepd to 30,000 boepd for the third quarter and approximately 30,000 boepd for the full year 2022. In June, we completed drilling operations on the Huron prospect (Hess 40%) located at Green Canyon Block 69. Well results are being evaluated and an appraisal sidetrack is planned.

•At the Stabroek Block (Hess 30%), offshore Guyana, net production totaled 67,000 bopd for the second quarter of 2022 (2021 Q2: 26,000 bopd). The Liza Destiny FPSO reached its new production capacity of more than 140,000 gross bopd in June following the completion of production optimization work. Net production from the Liza Unity FPSO, which commenced in February, was 35,000 bopd in the second quarter of 2022, and reached its production capacity of 220,000 gross bopd in July. In the second quarter, we sold 6 one-million barrel cargos of crude oil from Guyana compared with 2 one-million barrel cargos in the prior year quarter. We forecast net production to be in the range of 90,000 bopd to 95,000 bopd for the third quarter and approximately 75,000 bopd for the full year 2022, which includes tax barrels of approximately 7,000 bopd and 6,000 bopd, respectively.

Beginning in the third quarter of 2022, we expect to use the remainder of the previously generated Guyana net operating loss carryforwards. As a result, we will start to incur a current income tax liability. Pursuant to the terms of the petroleum agreement, a portion of gross production from the block, separate from the contractors’ share of gross production for cost oil and profit oil, is used to satisfy the contractors’ income tax liability. This portion of gross production, referred to as “tax barrels”, will be included in our reported production volumes and revenue will be recognized.

The third development, Payara, will utilize the Prosperity FPSO with an expected capacity of 220,000 gross bopd, with first production expected in late 2023. The fourth development, Yellowtail, was sanctioned in April and will utilize the ONE GUYANA FPSO with an expected capacity of 250,000 gross bopd, with first production expected in 2025.

In July, two new discoveries were announced at Seabob and Kiru-Kiru on the Stabroek Block. The Seabob-1 well encountered 131 feet of high quality oil bearing sandstone reservoirs. The well was drilled in 4,660 feet of water and is located approximately 12 miles southeast of the Yellowtail Field. The Kiru-Kiru-1 well, where drilling operations are ongoing, has thus far encountered 98 feet of high quality hydrocarbon bearing sandstone reservoirs. The well is being drilled in 5,760 feet of water and is located approximately 3 miles southeast of the Cataback-1 discovery.

•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged 41,000 boepd for the second quarter of 2022 (2021 Q2: 38,000 boepd), while net production from North Malay Basin, offshore Peninsular Malaysia, averaged 26,000 boepd for the second quarter of 2022 (2021 Q2: 28,000 boepd). Combined net production from JDA and North Malay Basin is forecast to be approximately 55,000 boepd in the third quarter and in the range of 60,000 boepd to 65,000 boepd for the full year 2022.

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 June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In millions, except per share amounts)									(In millions, except per share amounts)
Net Income (Loss) Attributable to Hess Corporation:
Net Income Attributable to Hess Corporation:										Net Income Attributable to Hess Corporation:
Exploration and Production	Exploration and Production	$	723	$	(25)	$	1,183	$	283	Exploration and Production	$	155	$	723	$	560	$	1,183
Midstream	Midstream	65		76		137		151		Midstream	62		65		123		137
Corporate, Interest and Other	Corporate, Interest and Other	(121)		(124)		(236)		(255)		Corporate, Interest and Other	(98)		(121)		(218)		(236)
Total	Total	$	667	$	(73)	$	1,084	$	179	Total	$	119	$	667	$	465	$	1,084
Net Income (Loss) Attributable to Hess Corporation Per Common Share:
Net Income Attributable to Hess Corporation Per Common Share:										Net Income Attributable to Hess Corporation Per Common Share:
Basic	Basic	$	2.15	$	(0.24)	$	3.50	$	0.58	Basic	$	0.39	$	2.15	$	1.52	$	3.50
Diluted	Diluted	$	2.15	$	(0.24)	$	3.49	$	0.58	Diluted	$	0.39	$	2.15	$	1.51	$	3.49

Items Affecting Comparability of Earnings Between Periods

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(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	$	—	$	(147)	$	—	$	(147)	Exploration and Production	$	(82)	$	—	$	(82)	$	—
Midstream	Midstream	—		—		—		—		Midstream	—		—		—		—
Corporate, Interest and Other	Corporate, Interest and Other	—		—		13		—		Corporate, Interest and Other	—		—		—		13
Total	Total	$	—	$	(147)	$	13	$	(147)	Total	$	(82)	$	—	$	(82)	$	13

The items in the table above are explained on pages 2524 and ~~27.~~26.

Reconciliations of GAAP and non-GAAP measures

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

Three Months Ended
June 30, Six Months Ended
June 30,
2022 2021 2022 2021
(In millions)
Adjusted Net Income (Loss) Attributable to Hess Corporation:
Net income (loss) attributable to Hess Corporation $ 667 $ (73) $ 1,084 $ 179
Less: Total items affecting comparability of earnings between periods, after-tax — (147) 13 (147)
Adjusted Net Income (Loss) Attributable to Hess Corporation $ 667 $ 74 $ 1,071 $ 326


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022

	(In millions)
Adjusted Net Income Attributable to Hess Corporation:
Net income attributable to Hess Corporation	$	119	$	667	$	465	$	1,084
Less: Total items affecting comparability of earnings between periods, after-tax	(82)		—		(82)		13
Adjusted Net Income Attributable to Hess Corporation	$	201	$	667	$	547	$	1,071

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:


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022

		(In millions)					(In millions)
Net cash provided by operating activities before changes in operating assets and liabilities:
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:
Net cash provided by (used in) operating activities	Net cash provided by (used in) operating activities	$	1,353	$	1,376	Net cash provided by (used in) operating activities	$	1,612	$	1,353
Changes in operating assets and liabilities	Changes in operating assets and liabilities	1,062		98		Changes in operating assets and liabilities	394		1,062
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	$	2,415	$	1,474	Net cash provided by (used in) operating activities before changes in operating assets and liabilities	$	2,006	$	2,415

2019

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 pages ~~25 through 27.~~24 and 26. 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.

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

Comparison of Results

Exploration and Production

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(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	$	2,955	$	1,579	$	5,268	$	3,477	Sales and other operating revenues	$	2,287	$	2,955	$	4,696	$	5,268

Other, net	Other, net	26		14		59		30		Other, net	8		26		22		59
Total revenues and non-operating income	Total revenues and non-operating income	2,981		1,593		5,327		3,507		Total revenues and non-operating income	2,295		2,981		4,718		5,327
Costs and Expenses	Costs and Expenses									Costs and Expenses
Marketing, including purchased oil and gas	Marketing, including purchased oil and gas	858		343		1,561		885		Marketing, including purchased oil and gas	564		858		1,183		1,561
Operating costs and expenses	Operating costs and expenses	291		254		542		462		Operating costs and expenses	384		291		707		542
Production and severance taxes	Production and severance taxes	67		44		128		81		Production and severance taxes	46		67		94		128
Midstream tariffs	Midstream tariffs	296		270		583		532		Midstream tariffs	302		296		585		583
Exploration expenses, including dry holes and lease impairment	Exploration expenses, including dry holes and lease impairment	33		48		76		81		Exploration expenses, including dry holes and lease impairment	99		33		165		76
General and administrative expenses	General and administrative expenses	47		49		104		98		General and administrative expenses	61		47		127		104
Depreciation, depletion and amortization	Depreciation, depletion and amortization	345		344		637		699		Depreciation, depletion and amortization	450		345		893		637
Impairment and other	Impairment and other	—		147		—		147		Impairment and other	82		—		82		—
Total costs and expenses	Total costs and expenses	1,937		1,499		3,631		2,985		Total costs and expenses	1,988		1,937		3,836		3,631
Results of Operations Before Income Taxes	Results of Operations Before Income Taxes	1,044		94		1,696		522		Results of Operations Before Income Taxes	307		1,044		882		1,696
Provision (benefit) for income taxes		321		119		513		239
Net Income (Loss) Attributable to Hess Corporation		$	723	$	(25)	$	1,183	$	283
Provision for income taxes										Provision for income taxes	152		321		322		513
Net Income Attributable to Hess Corporation										Net Income Attributable to Hess Corporation	$	155	$	723	$	560	$	1,183

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

2120

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Selling Prices: ~~Higher~~Lower realized selling prices in the second quarter and first six months of ~~2022, increased~~2023 reduced after-tax earnings by approximately ~~$675~~$840 million and ~~$1,105~~$1,250 million, respectively, compared towith the corresponding periods in ~~2021.~~2022. Average selling prices were as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

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)		$	93.60	$	56.75	$	88.98	$	49.35
North Dakota										North Dakota	$	65.67	$	93.60	$	67.05	$	88.98
Offshore	Offshore	95.22		59.33		90.21		55.99		Offshore	68.32		95.22		68.22		90.21
Total United States	Total United States	93.96		57.52		89.25		51.00		Total United States	66.24		93.96		67.32		89.25
Guyana	Guyana	104.19		65.63		100.55		62.48		Guyana	75.82		104.19		77.50		100.55
Malaysia and JDA	Malaysia and JDA	106.21		65.88		97.73		64.69		Malaysia and JDA	68.87		106.21		71.02		97.73
Other (c)		105.21		64.16		98.14		60.94
Other (b)										Other (b)	—		105.21		—		98.14
Worldwide	Worldwide	99.16		59.79		93.65		54.04		Worldwide	71.13		99.16		72.66		93.65
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)		$	106.01	$	61.88	$	98.46	$	52.91
North Dakota										North Dakota	$	69.22	$	106.01	$	70.41	$	98.46
Offshore	Offshore	107.58		64.42		99.58		60.24		Offshore	71.86		107.58		71.55		99.58
Total United States	Total United States	106.37		62.63		98.70		54.73		Total United States	69.79		106.37		70.68		98.70
Guyana	Guyana	112.57		68.44		109.06		64.48		Guyana	77.64		112.57		78.76		109.06
Malaysia and JDA	Malaysia and JDA	106.21		65.88		97.73		64.69		Malaysia and JDA	68.87		106.21		71.02		97.73
Other (c)		114.93		68.08		108.06		63.88
Other (b)										Other (b)	—		114.93		—		108.06
Worldwide	Worldwide	109.51		64.27		102.65		57.36		Worldwide	73.74		109.51		74.87		102.65
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	$	40.96	$	23.23	$	40.40	$	26.65	North Dakota	$	17.90	$	40.96	$	20.99	$	40.40
Offshore	Offshore	39.88		21.84		38.68		21.55		Offshore	20.17		39.88		22.20		38.68
Worldwide	Worldwide	40.92		23.12		40.33		26.20		Worldwide	17.95		40.92		21.02		40.33
Natural Gas – Per Mcf	Natural Gas – Per Mcf									Natural Gas – Per Mcf
United States	United States									United States
North Dakota	North Dakota	$	6.89	$	2.40	$	5.57	$	4.06	North Dakota	$	1.29	$	6.89	$	1.83	$	5.57
Offshore	Offshore	7.63		2.35		6.02		2.66		Offshore	1.62		7.63		2.03		6.02
Total United States	Total United States	7.06		2.38		5.67		3.56		Total United States	1.35		7.06		1.87		5.67
Malaysia and JDA	Malaysia and JDA	6.18		5.22		6.00		5.13		Malaysia and JDA	5.56		6.18		5.50		6.00
Other (c)		5.36		2.96		5.07		2.82
Other (b)										Other (b)	—		5.36		—		5.07
Worldwide	Worldwide	6.45		4.05		5.87		4.47		Worldwide	3.82		6.45		4.09		5.87

(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 second quarter of ~~2022~~2023 would be ~~$102.80 (Q2 2021: $62.45)~~$74.48 (2022 Q2: $102.80) per barrel for crude oil (including hedging), ~~$113.15 (Q2 2021: $66.93)~~$77.09 (2022 Q2: $113.15) per barrel for crude oil (excluding hedging), ~~$41.36 (Q2 2021: $23.35)~~$18.35 (2022 Q2: $41.36) per barrel for NGLs and ~~$6.55 (Q2 2021: $4.17)~~$3.95 (2022 Q2: $6.55) per mcf for natural gas. Excluding these fees worldwide selling prices for the first six months of ~~2022~~2023 would be ~~$97.63 (2021: $58.97)~~$76.05 (2022: $97.63) per barrel for crude oil (including hedging), ~~$106.63 (2021: $62.29)~~$78.26 (2022: $106.63) per barrel for crude oil (excluding hedging), ~~$40.65 (2021: $26.43)~~$21.33 (2022: $40.65) per barrel for NGLs and ~~$5.98 (2021: $4.59)~~$4.23 (2022: $5.98) per mcf for natural gas.

(b)~~Excluding the two very large crude carrier (VLCC) cargo sales totaling 4.2 million barrels~~Other includes our interest in the ~~first quarter of 2021, the North Dakota crude oil price for the first six months of 2021 excluding hedging~~Waha Concession in Libya, which was ~~$57.39 per barrel and $53.08 per barrel including hedging.~~

~~(c)Other includes Libya and our former interests in Denmark, which were~~ sold in ~~the third quarter of 2021.~~November 2022.

Crude oil hedging activities were a net loss of $52 million and $86 million before and after income taxes in the second quarter and first six months of 2023, respectively, and a net loss of $163 million and $255 million before and after income taxes in the second quarter and first six months of 2022, ~~respectively, and a net loss of $64 million and $115 million before and after income taxes in the second quarter and first six months of 2021,~~ respectively. For the remainder of ~~2022,~~2023, we have hedged ~~90,000~~80,000 bopd with WTI put options with an average monthly floor price of ~~$60~~$70 per barrel, and ~~60,000~~50,000 bopd with Brent put options with an average monthly floor price of ~~$65~~$75 per barrel. We expect noncash premium amortization, which will be reflected in realized selling prices, to reduce our results by $52 million in the third quarter and ~~fourth quarter results each~~ by ~~approximately $165 million.~~$190 million for the full year 2023.

2221

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In thousands)									(In thousands)
Crude Oil – Barrels	Crude Oil – Barrels									Crude Oil – Barrels
United States	United States									United States
North Dakota	North Dakota	68		79		73		82		North Dakota	79		68		78		73
Offshore	Offshore	20		33		20		34		Offshore	23		20		23		20
Total United States	Total United States	88		112		93		116		Total United States	102		88		101		93
Guyana	Guyana	67		26		49		29		Guyana	110		67		111		49
Malaysia and JDA	Malaysia and JDA	4		4		3		4		Malaysia and JDA	4		4		4		3
Other (a)	Other (a)	17		24		18		23		Other (a)	—		17		—		18
Total	Total	176		166		163		172		Total	216		176		216		163
Natural Gas Liquids – Barrels	Natural Gas Liquids – Barrels									Natural Gas Liquids – Barrels
United States	United States									United States
North Dakota	North Dakota	47		52		48		50		North Dakota	68		47		64		48
Offshore	Offshore	2		5		2		5		Offshore	1		2		2		2
Total United States	Total United States	49		57		50		55		Total United States	69		49		66		50
Natural Gas – Mcf	Natural Gas – Mcf									Natural Gas – Mcf
United States	United States									United States
North Dakota	North Dakota	147		167		152		159		North Dakota	206		147		182		152
Offshore	Offshore	41		85		41		90		Offshore	45		41		47		41
Total United States	Total United States	188		252		193		249		Total United States	251		188		229		193
Malaysia and JDA	Malaysia and JDA	381		371		373		366		Malaysia and JDA	359		381		363		373
Other (a)	Other (a)	11		9		12		10		Other (a)	—		11		—		12
Total	Total	580		632		578		625		Total	610		580		592		578
Barrels of Oil Equivalent (b)	Barrels of Oil Equivalent (b)	322		328		309		331		Barrels of Oil Equivalent (b)	387		322		381		309

Crude oil and natural gas liquids as a share of total production	Crude oil and natural gas liquids as a share of total production	70	%	68	%	69	%	69	%	Crude oil and natural gas liquids as a share of total production	74	%	70	%	74	%	69	%

(a)Other includes our interest in the Waha Concession in Libya, ~~and our former interests in Denmark,~~ which ~~were~~was sold in ~~the third quarter of 2021.~~November 2022. Net production from Libya was 19,000 boepd and 20,000 ~~boepd~~boped in the second quarter and first six months of 2022, respectively, compared with 21,000 boepd and 20,000 boepd in the second quarter and first six months of 2021, respectively. Net production from Denmark was 4,000 boepd and 5,000 boepd in the second quarter and first six months of 2021, respectively.

(b)Reflects natural gas production converted based on relative energy content (six mcf equals one barrel). Barrel of oil equivalence does not necessarily result in price equivalence as the equivalent price of natural gas on a barrel of oil equivalent basis has been substantially lower than the corresponding price for crude oil over the recent past. In addition, NGLs do not sell at prices equivalent to crude oil. See the average selling prices in the table on page ~~22.~~21.

We forecast net production ~~excluding Libya,~~ to be ~~in the range of 330,000 boepd to 335,000~~approximately 385,000 boepd for the third quarter and in the range of ~~365,000~~385,000 boepd to ~~370,000 boepd for the fourth quarter, and approximately 320,000~~390,000 boepd for the full year ~~2022.~~2023.

United States: North Dakota net production was ~~lower~~higher in the second quarter and first six months of ~~2022,~~2023, compared towith the corresponding periods in ~~2021, primarily~~2022, reflecting increased drilling and completion activity, higher NGL and natural gas volumes received under percentage of proceeds contracts due to ~~unplanned production~~lower commodity prices, and higher uptime after weather related shut-ins ~~caused by severe weather, and the sale of our Little Knife and Murphy Creek nonstrategic acreage interests~~ in the ~~second quarter of 2021.~~prior-year quarter. Total offshore net production was ~~lower~~higher in the second quarter and first six months of ~~2022,~~2023, compared towith the corresponding periods in ~~2021,~~2022, primarily due to ~~field decline and unplanned downtime~~an additional well brought online at the ~~Stampede, Penn State, and~~ Llano ~~fields.~~Field.

International: Net production in Guyana was higher in the second quarter and first six months of ~~2022,~~2023, compared towith the corresponding periods in ~~2021,~~2022, primarily due to production ramp up from the Liza Unity FPSO, which commenced production in February 2022 and reached its initial expected production capacity of approximately 220,000 gross bopd in July 2022. The Liza Unity FPSO is expected to increase its production capacity to approximately 250,000 gross bopd by the end of 2023 as a result of production optimization work. Net production from ~~the Liza Unity FPSO averaged 35,000~~Guyana included 13,000 bopd and ~~21,000~~14,000 bopd of tax barrels in the second quarter and first six months of ~~2022,~~2023, respectively. There were no tax barrels in either the second quarter or first six months of 2022.

2322

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Sales Volumes: ~~Lower~~Higher sales volumes in the second quarter and first six months of ~~2022 reduced~~2023 increased after-tax earnings by approximately ~~$30~~$620 million and ~~$290~~$1,210 million, respectively, compared towith the corresponding periods in ~~2021. Worldwide~~2022. Net worldwide sales volumes from Hess net production, which excludes sales volumes of crude oil, NGLs and natural gas purchased from third parties, were as follows:


		Three Months Ended June 30,		Six Months Ended June 30,			Three Months Ended June 30,		Six Months Ended June 30,
		2022	2021	2022	2021		2023	2022	2023	2022

		(In thousands)					(In thousands)
Crude oil – barrels ~~(a)~~	Crude oil – barrels ~~(a)~~	15,763	14,293	28,343	34,688	Crude oil – barrels ~~(a)~~	19,740	15,763	38,901	28,343
Natural gas liquids – barrels	Natural gas liquids – barrels	4,180	5,142	8,719	9,944	Natural gas liquids – barrels	6,084	4,180	11,845	8,719
Natural gas – mcf	Natural gas – mcf	52,811	57,557	104,709	113,070	Natural gas – mcf	55,548	52,811	107,240	104,709
Barrels of Oil Equivalent ~~(b)~~(a)	Barrels of Oil Equivalent ~~(b)~~(a)	28,745	29,028	54,514	63,477	Barrels of Oil Equivalent ~~(b)~~(a)	35,082	28,745	68,619	54,514
Crude oil – barrels per day	Crude oil – barrels per day	173	157	157	192	Crude oil – barrels per day	217	173	215	157
Natural gas liquids – barrels per day	Natural gas liquids – barrels per day	46	57	48	55	Natural gas liquids – barrels per day	67	46	65	48
Natural gas – mcf per day	Natural gas – mcf per day	580	632	578	625	Natural gas – mcf per day	610	580	592	578
Barrels of Oil Equivalent Per Day ~~(b)~~(a)	Barrels of Oil Equivalent Per Day ~~(b)~~(a)	316	319	301	351	Barrels of Oil Equivalent Per Day ~~(b)~~(a)	386	316	379	301

(a)~~Sales volumes for the first six months of 2021 include 4.2 million barrels that were stored on VLCCs at December 31, 2020 and sold 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 ~~22.~~21.

Marketing, including Purchased Oil and Gas: Marketing expense is mainly comprised of costs to purchase crude oil, NGL and natural gas from our partners in Hess operated wells or other third parties, primarily in the United States, and transportation and other distribution costs for U.S. and Guyana marketing activities. Marketing expense was ~~higher~~lower in the second quarter and first six months of ~~2022,~~2023, compared with the corresponding periods in ~~2021,~~2022, primarily due to ~~higher third party crude oil volumes purchased and higher~~lower prices paid for purchased volumes. ~~First quarter 2021 marketing expense included $173 million related to the cost of 4.2 million barrels of crude oil produced and stored on two VLCCs in 2020 that were sold in the 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 increased in the second quarter and first six months of ~~2022~~2023 compared with the corresponding periods in ~~2021,~~2022, primarily due to the production ramp up in Guyana from the Liza Unity FPSO, which commenced production in February 2022, increased maintenance activity in North Dakota, and higher workover costs in the Gulf of Mexico, partially offset by lower production and severance taxes associated with ~~higher~~lower crude oil prices. On a per-unit basis, the decrease in cash operating costs, proforma for asset sold, in the second quarter and first six months of ~~2022 reflect the higher costs and the impact of the lower production volumes~~2023, compared with the corresponding periods in ~~2021.~~2022, primarily reflects the impact of the higher production volumes.

Midstream Tariffs Expense: Tariffs expense ~~increased~~ in the second quarter and first six months of ~~2022,~~2023 increased, compared with the corresponding periods in ~~2021,~~2022, primarily due to higher throughput volumes and tariff rates partially offset by lower fees incurred under minimum volume commitments. We estimate Midstream tariffs expense to be in the range of ~~$305~~$320 million to ~~$315~~$330 million in the third quarter ~~of 2022~~ and in the range of ~~$1,190~~$1,230 million to ~~$1,215~~$1,250 million for the full year ~~2022.~~2023.

Depreciation, Depletion and Amortization (DD&A): DD&A expense ~~was lower~~and per-unit rates were higher in the second quarter and first six months of ~~2022,~~2023, compared with the corresponding ~~period~~periods in ~~2021,~~2022, primarily due to ~~lower~~higher production ~~volumes and lower DD&A rates resulting~~ from ~~year-end 2021 additions to proved reserves.~~Guyana following the start-up of Liza Phase 2 in February 2022.

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
		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,					Twelve Months Ended December 31,						Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,					Twelve Months Ended December 31,
		2022		2021		2022		2021		2022					2022						2023		2022		2023		2022		2023					2023
Cash operating costs ~~(b)~~(a)	Cash operating costs ~~(b)~~(a)	$	13.90	$	11.63	$	13.84	$	10.72	$	14.00	—	$	14.50	$	13.50	—	$	14.00	Cash operating costs ~~(b)~~(a)	$	13.97	$	13.90	$	13.48	$	13.84	$	14.00	—	$	14.50	$	13.50	—	$	14.00
DD&A ~~(c)~~(b)	DD&A ~~(c)~~(b)	11.79		11.55		11.39		11.69		13.00		—	13.50		12.50		—	13.00		DD&A ~~(c)~~(b)	12.79		11.79		12.97		11.39		12.50		—	13.00		13.00		—	13.50
Total Production Unit Costs	Total Production Unit Costs	$	25.69	$	23.18	$	25.23	$	22.41	$	27.00	—	$	28.00	$	26.00	—	$	27.00	Total Production Unit Costs	$	26.76	$	25.69	$	26.45	$	25.23	$	26.50	—	$	27.50	$	26.50	—	$	27.50

(a)~~Forecast information excludes any contribution from Libya.~~

~~(b)~~Cash operating costs per boe, excluding Libya (sold in November of 2022), were $14.56 and $14.55 in the second quarter and first six months of ~~2022, respectively, compared with $12.16 and $11.18 in the second quarter and first six months of 2021, respectively.~~2022.

~~(c)~~(b)DD&A per boe, excluding Libya (sold in November of 2022), was $12.34 and $11.96 in the second quarter and first six months of ~~2022, respectively, compared with $12.13 and $12.25 in the second quarter and first six months of 2021, respectively.~~2022.

2423

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Exploration Expenses: Exploration expenses were as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In millions)									(In millions)
Exploratory dry hole costs (a)	Exploratory dry hole costs (a)	$	—	$	9	$	—	$	9	Exploratory dry hole costs (a)	$	62	$	—	$	93	$	—
Exploration lease and other impairment		4		6		10		10
Exploration lease impairment										Exploration lease impairment	8		4		13		10
Geological and geophysical expense and exploration overhead	Geological and geophysical expense and exploration overhead	29		33		66		62		Geological and geophysical expense and exploration overhead	29		29		59		66
Total Exploration Expense	Total Exploration Expense	$	33	$	48	$	76	$	81	Total Exploration Expense	$	99	$	33	$	165	$	76

(a)~~The~~Exploratory dry hole costs in the second quarter ~~2021 dry hole costs~~of 2023 primarily relates to the ~~Koebi-1~~Ephesus exploration well, offshore Newfoundland, Canada and the Kokwari-1 exploration well at the Stabroek Block, offshore Guyana. Exploratory dry hole costs in the first six months of 2023 primarily relates to the Ephesus exploration well, offshore Newfoundland, Canada and the Kokwari-1 and Fish/Tarpon-1 exploration wells at the Stabroek Block, offshore Guyana.

Exploration expenses, excluding dry hole expense, are estimated to be ~~in the range of $35 million to $40~~approximately $60 million in the third quarter ~~of 2022~~ and ~~in the range of $160 million to~~approximately $170 million for the full year ~~2022.~~2023.

Income Taxes:

E&P income tax expense was $152 million and $322 million in the second quarter and first six months of 2023, respectively, compared with $321 million and $513 million in the second quarter and first six months of 2022, ~~respectively, compared with $119 million and $239 million in the second quarter and first six months of 2021,~~ respectively. ~~The increase in income tax expense, compared with the corresponding periods in 2021, was primarily due to higher pre-tax income in Libya and Guyana.~~ Income tax expense from Libya operations, sold in November 2022, was $177 million and $331 million in the second quarter and first six months of 2022, ~~respectively, compared with $96 million and $176 million~~respectively. The decrease in Libya income tax expense in the ~~second quarter and~~ first six months of ~~2021, respectively.~~ 2023, compared with the corresponding period in 2022, was partially offset by higher income tax expense in Guyana as a result of higher pre-tax income.

We are generally not recognizing deferred tax benefit or expense in certain countries, primarily the United States (non-Midstream), and Malaysia, while we maintain valuation allowances against net deferred tax assets in these jurisdictions in accordance with U.S. generally accepted accounting principles. As of June 30, 2023, we have a valuation allowance in our Consolidated Balance Sheet of $3.4 billion related to the ~~requirements~~United States and $0.1 billion related to Malaysia. There is a reasonable possibility that if anticipated future earnings come to fruition or are exceeded, and no other unforeseen negative evidence materializes, sufficient positive evidence may become available to support the release of ~~U.S. accounting standards.~~ a significant portion of the valuation allowance related to one or both jurisdictions in the near term. This would result in the recognition of certain deferred tax assets and a decrease to income tax expense for the period in which the release is recorded.

Excluding items affecting comparability of earnings between periods, ~~and Libyan operations,~~ E&P income tax expense is expected to be in the range of $170 million to $180 million for the third quarter ~~of 2022~~ and in the range of ~~$540~~$670 million to ~~$550~~$680 million for the full year ~~2022.~~2023.

Items Affecting Comparability of Earnings Between Periods:

In the second quarter of ~~2021,~~2023, we ~~recorded~~recognized a pre-tax charge of ~~$147~~$82 million ($~~147~~82 million after income taxes) ~~in connection with~~that resulted from revisions to our estimated abandonment obligations in the West Delta Field in the Gulf of Mexico. These abandonment obligations were assigned to us as a former owner after they were discharged from Fieldwood Energy LLC as part of ~~Fieldwood's~~its approved bankruptcy ~~plan.~~plan in 2021. See Note 8,7, Impairment and Other in the Notes toConsolidated Financial ~~Statements~~Statements.

2524

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

Midstream

Following is a summarized income statement for our Midstream operations:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(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	$	314	$	294	$	626	$	583	Sales and other operating revenues	$	324	$	314	$	629	$	626
Other, net	Other, net	—		3		1		6		Other, net	2		—		4		1
Total revenues and non-operating income	Total revenues and non-operating income	314		297		627		589		Total revenues and non-operating income	326		314		633		627
Costs and Expenses	Costs and Expenses									Costs and Expenses
Operating costs and expenses	Operating costs and expenses	68		64		134		124		Operating costs and expenses	73		68		136		134
General and administrative expenses	General and administrative expenses	5		4		11		11		General and administrative expenses	6		5		12		11
Interest expense	Interest expense	38		23		69		46		Interest expense	44		38		86		69
Depreciation, depletion and amortization	Depreciation, depletion and amortization	44		41		89		81		Depreciation, depletion and amortization	47		44		94		89
Total costs and expenses	Total costs and expenses	155		132		303		262		Total costs and expenses	170		155		328		303
Results of Operations Before Income Taxes	Results of Operations Before Income Taxes	159		165		324		327		Results of Operations Before Income Taxes	156		159		305		324
Provision (benefit) for income taxes		7		3		12		6
Net Income (Loss)		152		162		312		321
Less: Net income (loss) attributable to noncontrolling interests		87		86		175		170
Net Income (Loss) Attributable to Hess Corporation		$	65	$	76	$	137	$	151
Provision for income taxes										Provision for income taxes	8		7		14		12
Net Income										Net Income	148		152		291		312
Less: Net income attributable to noncontrolling interests										Less: Net income attributable to noncontrolling interests	86		87		168		175
Net Income Attributable to Hess Corporation										Net Income Attributable to Hess Corporation	$	62	$	65	$	123	$	137

Sales and other operating revenues for the second quarter and first six months of ~~2022~~2023 increased, compared towith the corresponding periods in ~~2021, primarily associated with higher minimum volume commitments.~~

~~Operating costs and expenses for the second quarter and first six months of~~ 2022, ~~increased, compared to the corresponding periods in 2021,~~ primarily due to higher ~~operating expenses on expanding gathering infrastructure. DD&A expense for the second quarter~~throughput volumes and ~~first six months of 2022 increased, compared to the corresponding periods in 2021, primarily due to additional assets placed in service.~~tariff rates partially offset by lower fees earned from minimum volume commitments. Interest expense for the second quarter of 2023 increased compared with the prior-year quarter due to higher interest rates on the term loan and revolving credit facilities. Interest expense in the first six months of ~~2022~~2023 increased, compared towith the corresponding ~~periods~~period in ~~2021, primarily~~2022, due to the $400 million of 5.500% fixed-rate senior unsecured notes issued in April 2022 and higher interest rates on the ~~$750 million of 4.250% fixed-rate senior unsecured notes issued in August 2021.~~term loan and revolving credit facilities.

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~~$55 million to ~~$65~~$60 million in the third quarter ~~of 2022~~ and in the range of ~~$265~~$240 million to ~~$275~~$250 million for the full year ~~2022.~~2023.

Corporate, Interest and Other

The following table summarizes Corporate, Interest and Other expenses:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022

		(In millions)									(In millions)
Corporate and other expenses		$	38	$	29	$	74	$	66
Corporate and other expenses (excluding items affecting comparability)										Corporate and other expenses (excluding items affecting comparability)	$	20	$	38	$	59	$	74
Interest expense	Interest expense	86		95		178		189		Interest expense	88		86		174		178
Less: Capitalized interest	Less: Capitalized interest	(3)		—		(3)		—		Less: Capitalized interest	(10)		(3)		(15)		(3)
Interest expense, net	Interest expense, net	83		95		175		189		Interest expense, net	78		83		159		175
Corporate, Interest and Other expenses before income taxes	Corporate, Interest and Other expenses before income taxes	121		124		249		255		Corporate, Interest and Other expenses before income taxes	98		121		218		249
Provision (benefit) for income taxes		—		—		—		—
Provision for income taxes										Provision for income taxes	—		—		—		—
Net Corporate, Interest and Other expenses after income taxes	Net Corporate, Interest and Other expenses after income taxes	121		124		249		255		Net Corporate, Interest and Other expenses after income taxes	98		121		218		249
Items affecting comparability of earnings between periods, after-tax	Items affecting comparability of earnings between periods, after-tax	—		—		(13)		—		Items affecting comparability of earnings between periods, after-tax	—		—		—		(13)
Total Corporate, Interest and Other Expenses after income taxes		$	121	$	124	$	236	$	255
Total Corporate, Interest and Other expenses after income taxes										Total Corporate, Interest and Other expenses after income taxes	$	98	$	121	$	218	$	236

Corporate and other expenses, excluding items affecting comparability, were lower in the second quarter of 2023 compared with the prior-year quarter, primarily due to higher interest income. Corporate and other expenses, excluding items affecting comparability, were lower in the first six months of 2023, compared with the corresponding period in 2022, primarily due to higher interest income partially offset by higher legal and professional fees. Interest expense, net was lower in the second quarter and first six months of ~~2022,~~2023, compared towith the corresponding periods in ~~2021,~~2022, primarily due to ~~higher legal~~capitalized interest associated with the Yellowtail and ~~professional fees.~~Uaru

2625

PART I - FINANCIAL INFORMATION (CONT'D.)

Consolidated Results of Operations (continued)

~~Interest expense, net was lower~~developments in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, due to the repayment of the Corporation's $1.0 billion term loan and capitalized interest that commenced upon sanctioning of the Yellowtail development in Guyana in April 2022.Guyana.

Third quarter ~~2022~~2023 corporate expenses are expected to be approximately ~~$40~~$25 million and ~~approximately $150~~in the range of $110 million to $120 million for the full year ~~2022.~~2023. Interest expense, net is expected to be ~~approximately $85~~in the range of $75 million to $80 million for the third quarter and in the range of ~~$345~~$300 million to ~~$350~~$310 million for the full year ~~2022.~~2023.

Items Affecting Comparability of Earnings Between Periods:

In the first ~~quarter~~six months of 2022, results included a pre-tax gain of $22 million ($22 million after income taxes) associated with the sale of real property and a charge of $9 million ($9 million after income taxes) for litigation related tocosts associated with our former downstream business.

Other Items Potentially Affecting Future Results

Our future results may be impacted by a variety of factors, including but not limited to, volatility in the selling prices of crude oil, NGLs and natural gas, reserve and production changes, asset sales, impairment charges and exploration expenses, industry cost inflation and/or deflation, changes in foreign exchange rates and income tax rates, changes in deferred tax asset valuation allowances, the effects of weather, crude oil storage capacity, political risk, environmental risk and catastrophic ~~risk, including risks associated with the global COVID-19 pandemic (COVID-19).~~risk. For a more comprehensive description of the risks that may affect our business, see Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, ~~2021.~~2022.

Liquidity and Capital Resources

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


		June 30, 2022			December 31, 2021				June 30, 2023			December 31, 2022

		(In millions, except ratio)							(In millions, except ratio)
Cash and cash equivalents (a)	Cash and cash equivalents (a)	$	2,159		$	2,713		Cash and cash equivalents (a)	$	2,226		$	2,486
Current portion of long-term debt	Current portion of long-term debt	—			517			Current portion of long-term debt	8			3
Total debt (b)	Total debt (b)	8,332			8,458			Total debt (b)	8,467			8,281
Total equity	Total equity	7,758			7,026			Total equity	8,902			8,496
Debt to capitalization ratio for debt covenants (c)	Debt to capitalization ratio for debt covenants (c)	37.9		%	42.3		%	Debt to capitalization ratio for debt covenants (c)	35.1		%	36.1		%

(a)Includes $3$4 million of cash attributable to our Midstream segment at June 30, ~~2022~~2023 (December 31, ~~2021: $2~~2022: $4 million) of which $2$3 million is held by Hess Midstream LP at June 30, ~~2022~~2023 (December 31, ~~2021: $2~~2022: $3 million).

(b)At June 30, ~~2022,~~2023, includes ~~$2,937~~$3,069 million of debt outstanding from our Midstream segment (December 31, ~~2021: $2,564~~2022: $2,886 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 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:


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022

		(In millions)					(In millions)
Net cash provided by (used in):	Net cash provided by (used in):					Net cash provided by (used in):
Operating activities	Operating activities	$	1,353	$	1,376	Operating activities	$	1,612	$	1,353
Investing activities	Investing activities	(1,181)		(445)		Investing activities	(1,662)		(1,181)
Financing activities	Financing activities	(726)		(240)		Financing activities	(210)		(726)
Net Increase (Decrease) in Cash and Cash Equivalents	Net Increase (Decrease) in Cash and Cash Equivalents	$	(554)	$	691	Net Increase (Decrease) in Cash and Cash Equivalents	$	(260)	$	(554)

2726

PART I - FINANCIAL INFORMATION (CONT'D.)

Liquidity and Capital Resources (continued)

Operating activities: Net cash provided by operating activities was ~~$1,353~~$1,612 million in the first six months of ~~2022, compared with $1,376 million in the first six months of 2021.~~2023 (2022: $1,353 million). Net cash provided by operating activities before changes in operating assets and liabilities was ~~$2,415~~$2,006 million in the first six months of ~~2022, compared with $1,474 million in the first six months of 2021 primarily due to higher realized selling prices.~~2023 (2022: $2,415 million). During the first six months of ~~2022,~~2023, changes in operating assets and liabilities reduced ~~net~~ cash ~~provided~~flow from operating activities by $394 million primarily due to premiums paid for crude oil hedge contracts and payments for abandonment activities. Changes in operating assets and liabilities in the first six months of 2022 reduced cash flow from operating activities by $1,062 million ~~(2021: $98 million)~~ reflecting payments ~~made~~of approximately $470 million for ~~previously~~ accrued Libyan income tax and royalties ~~of approximately $470 million for the period~~at December ~~2020 through November~~31, 2021, premiums paid ~~of $325 million to remove the ceiling price on outstanding WTI and Brent~~for crude oil ~~price collars effective April 1, 2022,~~hedge contracts and an increase in accounts receivable due to higher crude oil prices.

Investing activities: Additions to property, plant and equipment of ~~$1,209~~$1,658 million in the first six months of ~~2022~~2023 were up ~~$469~~$449 million compared with the corresponding period in ~~2021.~~2022. The increase is primarily due to ~~higher drilling and~~ development activities in Guyana ~~the Bakken, Malaysia~~ and ~~JDA, and the Gulf of Mexico. Proceeds from asset sales~~higher drilling activity in the ~~first six months of 2022 were $28 million and $297 million in the first six months of 2021.~~Bakken.

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


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022

		(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	$	(1,136)	$	(676)	Capital expenditures incurred - E&P	$	(1,639)	$	(1,136)
Increase (decrease) in related liabilities	Increase (decrease) in related liabilities	38		(11)		Increase (decrease) in related liabilities	88		38
Additions to property, plant and equipment - E&P	Additions to property, plant and equipment - E&P	$	(1,098)	$	(687)	Additions to property, plant and equipment - E&P	$	(1,551)	$	(1,098)
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	$	(109)	$	(70)	Capital expenditures incurred - Midstream	$	(109)	$	(109)
Increase (decrease) in related liabilities	Increase (decrease) in related liabilities	(2)		17		Increase (decrease) in related liabilities	2		(2)
Additions to property, plant and equipment - Midstream	Additions to property, plant and equipment - Midstream	$	(111)	$	(53)	Additions to property, plant and equipment - Midstream	$	(107)	$	(111)

Financing activities:

Common stock dividends paid were $271 million in the first six months of 2023 (2022: $235 million) reflecting a 17% increase in our dividend on common stock. In the first six months of 2022, we repurchased $190 million of common stock and ~~paid common stock dividends of $235 million (2021: $157 million) reflecting a 50% increase in our dividend on common stock. In the first six months of 2022,~~ we repaid the remaining $500 million outstanding under our $1.0 billion term ~~loan, previously scheduled to mature in March 2023.~~loan.

~~In the second quarter~~Net borrowings (repayments) of ~~2022, we received net proceeds~~debt with maturities of ~~$146 million from the public offering of approximately 5.1 million Hess-owned Class A shares in Hess Midstream LP, and~~90 days or less in the first ~~quarter~~six months of ~~2021, we received net proceeds~~2023 related to the HESM Opco revolving credit facility, while borrowings in the first six months of ~~$70 million from the public offering of approximately 3.5 million Hess-owned Class A shares in Hess Midstream LP. Borrowings in~~ 2022 resulted from the issuance by HESM Opco of $400 million of 5.500% fixed-rate senior unsecured notes due 2030. The proceeds from these borrowings were used to finance the repurchases of HESM Opco Class B units. In the first six months of 2023, we received net proceeds of $167 million from the public offering of Class A shares in Hess Midstream LP (2022: $146 million). Net cash outflows to noncontrolling interests were ~~$351~~$263 million in the first six months of ~~2022 (2021: $137~~2023 (2022: $351 million) which included ~~$200~~$100 million paid to GIP for the repurchase by HESM Opco of ~~approximately 6.8 million~~ GIP-owned Class B ~~units.~~units (2022: $200 million).

Future Capital Requirements and Resources

At June 30, ~~2022,~~2023, we had ~~$2.16~~$2.2 billion in cash and cash equivalents, excluding Midstream, and total liquidity, including available committed credit facilities, of approximately ~~$5.73~~$5.6 billion. ~~In June 2022, we repurchased $190 million (1.8 million shares) of our common stock.~~ We intend to utilize the remaining amount authorized under our stock repurchase plan of $460 million by the end of the year. In March 2022, we announced a 50% increase in our dividend on common stock. As we become increasingly free cash flow positive, we plan to return up to 75% of our annual adjusted free cash flow (defined as net cash provided by operating activities less capital expenditures and adjusted for debt repayments and net Midstream financing activities) to shareholders through ~~further~~ dividend increases ~~and/or~~and common stock repurchases. In March 2023, we announced a 17% increase in our first quarter dividend on common stock and our Board of Directors approved a new authorization for the repurchase of our common stock in an aggregate amount of up to $1 billion.

Net production in 2023 is forecast to be in the range of 385,000 boepd to 390,000 boepd, and we expect our 2023 E&P capital and exploratory expenditures will be approximately $3.7 billion. In ~~2022,~~2023, based on current forward strip crude oil prices, we expect cash flow from operating activities and cash and cash equivalents at June 30, ~~2022,~~2023 will be sufficient to fund our capital investment and 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.

2827

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 June 30, ~~2022:~~2023:


		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 2024	$	3,500	$	—	$	—	$	—	$	3,500	Revolving credit facility	July 2027	$	3,250	$	—	$	—	$	—	$	3,250
Committed lines	Committed lines	Various (a)	100		—		29		29		71		Committed lines	Various (a)	100		—		2		2		98
Uncommitted lines	Uncommitted lines	Various (a)	121		—		121		121		—		Uncommitted lines	Various (a)	87		—		87		87		—
Total - Hess Corporation	Total - Hess Corporation		$	3,721	$	—	$	150	$	150	$	3,571	Total - Hess Corporation		$	3,437	$	—	$	89	$	89	$	3,348
Midstream	Midstream												Midstream
Revolving credit facility (b)	Revolving credit facility (b)	December 2024	$	1,000	$	91	$	—	$	91	$	909	Revolving credit facility (b)	July 2027	$	1,000	$	198	$	—	$	198	$	802
Total - Midstream	Total - Midstream		$	1,000	$	91	$	—	$	91	$	909	Total - Midstream		$	1,000	$	198	$	—	$	198	$	802

(a)Committed and uncommitted lines have expiration dates through ~~2022.~~2024.

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

Hess Corporation:

~~At June 30, 2022, we had a $3.5 billion revolving credit facility expiring in May 2024.~~ The revolving credit facility can be used for borrowings and letters of credit. Borrowings on the facility will generally bear interest at ~~1.40%~~1.400% above ~~LIBOR,~~SOFR, though the interest rate is subject to adjustment ifbased on the ~~Corporation’s~~ credit rating ~~changes.~~of the Corporation's senior, unsecured, non-credit enhanced long-term debt. The revolving credit facility 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). The indentures for the Corporation's fixed-rate ~~public~~senior unsecured notes limit the ratio of secured debt to Consolidated Net Tangible Assets (as that term is defined in the indentures) to 15%. As of June 30, ~~2022,~~2023, Hess Corporation was in compliance with these financial covenants.

~~In July 2022, we replaced our $3.5 billion~~ At June 30, 2023, Hess Corporation had no outstanding borrowings or letters of credit under its revolving credit ~~facility expiring in May 2024 with a new $3.25 billion revolving credit facility maturing in July 2027. See~~ ~~Note 14, Subsequent Events~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~.facility.

All three major credit rating agencies that rate ~~our~~the senior unsecured debt of Hess Corporation have assigned an investment grade credit rating. InAt June ~~2022,~~30, 2023, our credit ratings were BBB- with stable outlook at Standard and Poor’s, Baa3 with stable outlook at Moody’s Investors Service, ~~upgraded the senior unsecured ratings of Hess Corporation from Ba1 to Baa3 with a stable outlook. In March 2022, Standard~~ and ~~Poor’s Ratings Services affirmed our credit rating at~~ BBB- with ~~stable outlook.~~positive outlook at Fitch ~~Ratings affirmed our BBB- credit rating and revised the outlook from stable to positive in August 2021.~~Ratings.

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

Midstream:

At June 30, ~~2022,~~2023, HESM Opco, a consolidated subsidiary of Hess Midstream LP, had $1.4 billion of senior secured syndicated credit facilities, ~~maturing in December 2024,~~ consisting of a $1.0 billion revolving credit facility and a ~~fully drawn~~ $400 million term loan. 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.loan facility. Borrowings under the ~~five year~~ term loan A facility will generally bear interest at ~~LIBOR~~SOFR plus an applicable margin ranging from ~~1.55%~~1.650% to ~~2.50%~~2.550%, while the applicable margin for the ~~five year~~ syndicated revolving credit facility ranges from ~~1.275%~~1.375% to ~~2.000%~~2.050%. Pricing levels for the facility fee and interest-rate margins are based on HESM Opco’s ratio of total debt to EBITDA (as defined in the credit facilities). If HESM Opco obtains an investment grade credit rating, the pricing levels will be based on HESM Opco’s credit ratings in effect from time to time. The credit facilities contain covenants that require HESM Opco to maintain a ratio of total debt to EBITDA (as defined in the credit facilities) for the prior four fiscal quarters of not greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to HESM Opco obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter. ~~HESM Opco was in compliance with these financial covenants at June 30, 2022.~~ The credit facilities are secured by first-priority perfected liens on substantially all of the assets of HESM Opco and its direct and indirect wholly owned material domestic subsidiaries, including equity interests directly owned by such entities, subject to certain customary exclusions. At June 30, ~~2022,~~2023, borrowings of ~~$91~~$198 million were drawn under HESM Opco’s revolving credit facility, and borrowings of ~~$380~~$400 million, excluding deferred issuance costs, were drawn under HESM Opco’s term loan A facility. Borrowings under these credit facilities are non-recourse to Hess Corporation.

~~In July 2022, HESM Opco amended and restated the credit agreement for its senior secured syndicated credit facilities. See~~ ~~Note 14, Subsequent Events~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~.

PART I - FINANCIAL INFORMATION (CONT'D.)

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 ~~13,~~12, Financial Risk Management Activities, in the Notes to Consolidated Financial Statements.

We have outstanding foreign exchange contracts with notional amounts totaling ~~$157~~$236 million at June 30, ~~2022~~2023 that are used to reduce our exposure to fluctuating foreign exchange rates for various currencies. AThe change in fair value of foreign exchange contracts from a 10% strengthening or weakening in the U.S. Dollar exchange rate is estimated to be a gain or loss ~~respectively,~~ of approximately ~~$15~~$20 million and $25 million, respectively, at June 30, ~~2022.~~2023.

At June 30, ~~2022, consolidated~~2023, our long-term debt, which was substantially comprised of fixed-rate instruments, had a carrying value of ~~$8,332~~$8,467 million and a fair value of ~~$8,297~~$8,374 million. A 15% increase or decrease in interest rates would decrease or increase the fair value of debt by approximately ~~$460~~$445 million or ~~$555~~$490 million, ~~respectively.~~respectively, at June 30, 2023. Any changes in interest rates do not impact our cash outflows associated with fixed-rate interest payments or settlement of debt principal, unless a debt instrument is repurchased prior to maturity.

At June 30, ~~2022,~~2023, we have WTI put options with an average monthly floor price of ~~$60~~$70 per barrel for ~~90,000~~80,000 bopd, and Brent put options with an average monthly floor price of ~~$65~~$75 per barrel for ~~60,000~~50,000 bopd. As of June 30, ~~2022,~~2023, 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 $5$50 million, while an assumed 10% decrease in the same crude oil prices would increase the fair value of these derivative instruments by approximately ~~$10~~$100 million.

3029

PART I - FINANCIAL INFORMATION (CONT'D.)

Cautionary Note Regarding Forward-Looking Statements

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

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

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

•reduced demand for our products, including due to ~~COVID-19,~~ perceptions regarding the 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 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 and other events, such as accidents, severe weather, geological events, shortages of skilled labor, cyber-attacks, public health measures, ~~related to 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 and exposure to decommissioning liabilities for divested assets in the event the current or future owners are unable to 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 limitations on investment in oil and gas activities, rising interest rates 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—Risk Factors in our Annual Report on Form 10-K for the year ended December 31, ~~2021~~2022 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.

3130

PART I - FINANCIAL INFORMATION (CONT'D.)

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

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

Item 4. Controls and Procedures.

Based upon their evaluation of the Corporation’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, ~~2022,~~2023, John B. Hess, Chief Executive Officer, and John P. Rielly, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of June 30, ~~2022.~~2023.

There was no change in internal control over financial reporting identified in connection with the evaluation required by paragraph (d) of Rules 13a-15 or 15d-15 in the quarter ended June 30, ~~2022~~2023 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

3231

PART II –- OTHER INFORMATION

Item 1. Legal Proceedings.

Information regarding legal proceedings is contained in Note ~~11,~~10, Guarantees and Contingencies in the Notes to Consolidated Financial Statements and is incorporated herein by reference.

Item 2. Share Repurchase Activities.

~~Our~~On March 1, 2023, our Board of Directors approved a new authorization for the repurchase of our common stock in an aggregate amount of up to $1 billion. This new authorization replaced our previous repurchase ~~activities for~~authorization which was fully utilized at the end of 2022. There were no shares of our common stock repurchased during the second quarter of 2023.

Item 5. Other Information.

During the three months ended June 30, ~~2022, were~~2023, none of our directors or officers (as defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as ~~follows:~~

Period Total Number of
Shares Purchased (a) Average
Price Paid
per Share (a) Total Number of
Shares Purchased as
Part of Publicly
Announced Plans or
Programs (b) Maximum Approximate
Dollar Value of
Shares that May
Yet be Purchased
Under the Plans
or Programs (c)
(In millions)
April — $ — — $ 650
May — — — 650
June 1,753,918 108.49 1,753,918 460
Total 1,753,918 $ 108.49 1,753,918

~~(a)Repurchased~~each term is defined in ~~open-market transactions. The average price paid per share was inclusive~~Item 408(a) of ~~transaction fees.~~

~~(b)Since initiation of the buyback program in August 2013, total shares repurchased through June 30, 2022 amounted to 93.6 million at a total cost of $7.04 billion including transaction fees.~~

~~(c)~~In March 2013, we announced that our Board of Directors approved a stock repurchase program that authorized the purchase of common stock up to a value of $4.0 billion. In May 2014, the share repurchase program was increased to $6.5 billion and in March 2018, it was increased further to $7.5 billion.Regulation S-K.

3332

PART II –- OTHER INFORMATION (CONT'D)

Item 6. Exhibits.


Exhibits
4 ~~(1)~~			~~Credit Agreement, dated as of July 14, 2022, among Hess Corporation, the subsidiary party thereto, the lenders party thereto, and JPMorgan Chase Bank, N.A., as administrative agentincorporated by reference to Exhibit 10(1) of Form 8-K of the Registrant, filed on July 15, 2022.~~
31(1)			Certification required by Rule 13a-14(a) (17 CFR 240.13a-14(a)) or Rule 15d-14(a) (17 CFR 240.15d-14(a)).
31(2)			Certification required by Rule 13a-14(a) (17 CFR 240.13a-14(a)) or Rule 15d-14(a) (17 CFR 240.15d-14(a)).
32(1)#			Certification required by Rule 13a-14(b) (17 CFR 240.13a-14(b)) or Rule 15d-14(b) (17 CFR 240.15d-14(b)) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350).
32(2)#			Certification required by Rule 13a-14(b) (17 CFR 240.13a-14(b)) or Rule 15d-14(b) (17 CFR 240.15d-14(b)) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350).
101(INS)			Inline XBRL Instance Document- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101(SCH)			Inline XBRL Taxonomy Extension Schema Document.
101(CAL)			Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101(LAB)			Inline XBRL Taxonomy Extension Label Linkbase Document.
101(PRE)			Inline XBRL Taxonomy Extension Presentation Linkbase Document.
101(DEF)			Inline XBRL Taxonomy Extension Definition Linkbase Document.
104			The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, ~~2022,~~2023, has been formatted in Inline XBRL.

#Furnished herewith.

SIGNATURES

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


HESS CORPORATION
(REGISTRANT)


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


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

Date: August ~~4, 2022~~3, 2023

3534


Period	Total Number of Shares Purchased (a)	Average Price Paid per Share (a)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (b)	Maximum Approximate Dollar Value of Shares that May Yet be Purchased Under the Plans or Programs (c) (In millions)
April	—	$	—	—	$	650
May	—	—		—	650
June	1,753,918	108.49		1,753,918	460
Total	1,753,918	$	108.49	1,753,918