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, 20222023
or
 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                     to                     
Commission File Number 1-1204 
HESS CORPORATION
(Exact Name of Registrant as Specified in Its Charter)
DELAWARE
(State or Other Jurisdiction of Incorporation or Organization)
13-4921002
(I.R.S. Employer Identification Number)

1185 AVENUE OF THE AMERICAS, NEW YORK, NY
(Address of Principal Executive Offices)
10036
(Zip Code)
(Registrant’s Telephone Number, Including Area Code is (212) 997-8500)
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading SymbolName of exchange on which registered
Common StockHESNew 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 309,614,906307,061,031 shares of Common Stock outstanding.




HESS CORPORATION
Form 10-Q
TABLE OF CONTENTS
 
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2.2.
 
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)
AssetsAssets  Assets  
Current Assets:Current Assets:  Current Assets:  
Cash and cash equivalentsCash and cash equivalents$2,159 $2,713 Cash and cash equivalents$2,226 $2,486 
Accounts receivable:Accounts receivable:Accounts receivable:
From contracts with customersFrom contracts with customers1,265 1,062 From contracts with customers868 1,041 
Joint venture and otherJoint venture and other141 149 Joint venture and other151 121 
InventoriesInventories317 223 Inventories278 217 
Other current assetsOther current assets87 199 Other current assets181 66 
Total current assetsTotal current assets3,969 4,346 Total current assets3,704 3,931 
Property, plant and equipment:Property, plant and equipment:Property, plant and equipment:
Total — at costTotal — at cost32,402 31,178 Total — at cost34,073 32,592 
Less: Reserves for depreciation, depletion, amortization and lease impairmentLess: Reserves for depreciation, depletion, amortization and lease impairment17,584 16,996 Less: Reserves for depreciation, depletion, amortization and lease impairment18,332 17,494 
Property, plant and equipment — netProperty, plant and equipment — net14,818 14,182 Property, plant and equipment — net15,741 15,098 
Operating lease right-of-use assets — netOperating lease right-of-use assets — net446 352 Operating lease right-of-use assets — net515 570 
Finance lease right-of-use assets — netFinance lease right-of-use assets — net136 144 Finance lease right-of-use assets — net117 126 
GoodwillGoodwill360 360 Goodwill360 360 
Deferred income taxesDeferred income taxes147 71 Deferred income taxes214 133 
Post-retirement benefit assetsPost-retirement benefit assets603 409 Post-retirement benefit assets664 648 
Other assetsOther assets701 651 Other assets915 829 
Total AssetsTotal Assets$21,180 $20,515 Total Assets$22,230 $21,695 
LiabilitiesLiabilitiesLiabilities
Current Liabilities:Current Liabilities:Current Liabilities:
Accounts payableAccounts payable$359 $220 Accounts payable$350 $285 
Accrued liabilitiesAccrued liabilities1,741 1,710 Accrued liabilities1,754 1,840 
Taxes payableTaxes payable141 528 Taxes payable69 47 
Current portion of long-term debtCurrent portion of long-term debt— 517 Current portion of long-term debt
Current portion of operating and finance lease obligationsCurrent portion of operating and finance lease obligations114 89 Current portion of operating and finance lease obligations222 221 
Total current liabilitiesTotal current liabilities2,355 3,064 Total current liabilities2,403 2,396 
Long-term debtLong-term debt8,332 7,941 Long-term debt8,459 8,278 
Long-term operating lease obligationsLong-term operating lease obligations457 394 Long-term operating lease obligations407 469 
Long-term finance lease obligationsLong-term finance lease obligations190 200 Long-term finance lease obligations168 179 
Deferred income taxesDeferred income taxes544 383 Deferred income taxes497 418 
Asset retirement obligationsAsset retirement obligations1,028 1,005 Asset retirement obligations960 1,034 
Other liabilities and deferred creditsOther liabilities and deferred credits516 502 Other liabilities and deferred credits434 425 
Total LiabilitiesTotal Liabilities13,422 13,489 Total Liabilities13,328 13,199 
EquityEquityEquity
Hess Corporation stockholders’ equity:Hess Corporation stockholders’ equity:Hess Corporation stockholders’ equity:
Common stock, par value $1.00; Authorized — 600,000,000 sharesCommon stock, par value $1.00; Authorized — 600,000,000 sharesCommon 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 valueCapital in excess of par value6,236 6,017 Capital in excess of par value6,442 6,206 
Retained earningsRetained earnings1,075 379 Retained earnings1,670 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’ equityTotal Hess Corporation stockholders’ equity7,136 6,300 Total Hess Corporation stockholders’ equity8,272 7,855 
Noncontrolling interestsNoncontrolling interests622 726 Noncontrolling interests630 641 
Total EquityTotal Equity7,758 7,026 Total Equity8,902 8,496 
Total Liabilities and EquityTotal Liabilities and Equity$21,180 $20,515 Total Liabilities and Equity$22,230 $21,695 
See accompanying Notes to Consolidated Financial Statements.
2


PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED INCOME (UNAUDITED)
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
2022202120222021 2023202220232022
(In millions, except per share amounts) (In millions, except per share amounts)
Revenues and Non-Operating IncomeRevenues and Non-Operating Income  Revenues and Non-Operating Income  
Sales and other operating revenuesSales 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, netGains on asset sales, net— 25 — Gains on asset sales, net— — 25 
Other, netOther, net30 19 66 40 Other, net31 30 73 66 
Total revenues and non-operating incomeTotal revenues and non-operating income2,988 1,598 5,359 3,517 Total revenues and non-operating income2,320 2,988 4,773 5,359 
Costs and ExpensesCosts and ExpensesCosts and Expenses
Marketing, including purchased oil and gasMarketing, including purchased oil and gas843 322 1,525 840 Marketing, including purchased oil and gas547 843 1,150 1,525 
Operating costs and expensesOperating costs and expenses356 315 669 580 Operating costs and expenses454 356 836 669 
Production and severance taxesProduction and severance taxes67 44 128 81 Production and severance taxes46 67 94 128 
Exploration expenses, including dry holes and lease impairmentExploration expenses, including dry holes and lease impairment33 48 76 81 Exploration expenses, including dry holes and lease impairment99 33 165 76 
General and administrative expensesGeneral and administrative expenses95 84 205 178 General and administrative expenses108 95 244 205 
Interest expenseInterest expense121 118 244 235 Interest expense122 121 245 244 
Depreciation, depletion and amortizationDepreciation, depletion and amortization391 385 728 781 Depreciation, depletion and amortization497 391 988 728 
Impairment and otherImpairment and other— 147 — 147 Impairment and other82 — 82 — 
Total costs and expensesTotal costs and expenses1,906 1,463 3,575 2,923 Total costs and expenses1,955 1,906 3,804 3,575 
Income (Loss) Before Income Taxes1,082 135 1,784 594 
Provision (benefit) for income taxes328 122 525 245 
Net Income (Loss)754 13 1,259 349 
Less: Net income (loss) attributable to noncontrolling interests87 86 175 170 
Net Income (Loss) Attributable to Hess Corporation$667 $(73)$1,084 $179 
Income Before Income TaxesIncome Before Income Taxes365 1,082 969 1,784 
Provision for income taxesProvision for income taxes160 328 336 525 
Net IncomeNet Income205 754 633 1,259 
Less: Net income attributable to noncontrolling interestsLess: Net income attributable to noncontrolling interests86 87 168 175 
Net Income Attributable to Hess CorporationNet 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:
BasicBasic$2.15 $(0.24)$3.50 $0.58 Basic$0.39 $2.15 $1.52 $3.50 
DilutedDiluted$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:
BasicBasic309.7 307.5 309.3 306.7 Basic306.0 309.7 305.7 309.3 
DilutedDiluted310.9 307.5 310.6 308.7 Diluted307.5 310.9 307.4 310.6 
Common Stock Dividends Per ShareCommon 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.

3


PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
2022202120222021 2023202220232022
(In millions) (In millions)
Net Income (Loss)$754 $13 $1,259 $349 
Net IncomeNet Income$205 $754 $633 $1,259 
Other Comprehensive Income (Loss):Other Comprehensive Income (Loss):Other Comprehensive Income (Loss):
Derivatives designated as cash flow hedgesDerivatives designated as cash flow hedgesDerivatives designated as cash flow hedges
Effect of hedge (gains) losses reclassified to incomeEffect of hedge (gains) losses reclassified to income163 64 255 115 Effect of hedge (gains) losses reclassified to income52 163 86 255 
Income taxes on effect of hedge (gains) losses reclassified to incomeIncome 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 incomeNet effect of hedge (gains) losses reclassified to income163 64 255 115 Net effect of hedge (gains) losses reclassified to income52 163 86 255 
Change in fair value of cash flow hedgesChange 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 hedgesIncome 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 hedgesNet 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 taxesChange in derivatives designated as cash flow hedges, after taxes124 (65)(239)(116)Change in derivatives designated as cash flow hedges, after taxes(21)124 (4)(239)
Pension and other postretirement plansPension and other postretirement plansPension and other postretirement plans
(Increase) reduction in unrecognized actuarial losses(Increase) reduction in unrecognized actuarial losses152 (11)152 (Increase) reduction in unrecognized actuarial losses(13)152 (13)152 
Income taxes on actuarial changes in plan liabilitiesIncome 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, net152 (11)152 (Increase) reduction in unrecognized actuarial losses, net(13)152 (13)152 
Amortization of net actuarial lossesAmortization of net actuarial losses16 32 Amortization of net actuarial losses
Income taxes on amortization of net actuarial lossesIncome taxes on amortization of net actuarial losses— — — — Income taxes on amortization of net actuarial losses— — — — 
Net effect of amortization of net actuarial lossesNet effect of amortization of net actuarial losses16 32 Net effect of amortization of net actuarial losses
Change in pension and other postretirement plans, after taxesChange in pension and other postretirement plans, after taxes157 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 interests87 86 175 170 
Comprehensive Income (Loss) Attributable to Hess Corporation$948 $(133)$1,005 $98 
Comprehensive IncomeComprehensive Income172 1,035 617 1,180 
Less: Comprehensive income attributable to noncontrolling interestsLess: Comprehensive income attributable to noncontrolling interests86 87 168 175 
Comprehensive Income Attributable to Hess CorporationComprehensive Income Attributable to Hess Corporation$86 $948 $449 $1,005 
See accompanying Notes to Consolidated Financial Statements.

4


PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS (UNAUDITED)
Six Months Ended
June 30,
Six Months Ended
June 30,
20222021 20232022
(In millions) (In millions)
Cash Flows From Operating ActivitiesCash 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 incomeNet 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 amortizationDepreciation, depletion and amortization728 781 Depreciation, depletion and amortization988 728 
Impairment and otherImpairment and other— 147 Impairment and other82 — 
Exploratory dry hole costsExploratory dry hole costs— Exploratory dry hole costs93 — 
Exploration lease and other impairment10 10 
Exploration lease impairmentExploration lease impairment13 10 
Pension settlement lossPension settlement lossPension settlement loss— 
Stock compensation expenseStock compensation expense49 44 Stock compensation expense53 49 
Noncash (gains) losses on commodity derivatives, netNoncash (gains) losses on commodity derivatives, net218 88 Noncash (gains) losses on commodity derivatives, net52 218 
Provision (benefit) for deferred income taxes and other tax accruals174 42 
Provision for deferred income taxes and other tax accrualsProvision for deferred income taxes and other tax accruals92 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 liabilitiesIncrease (decrease) in accounts payable and accrued liabilities100 (56)Increase (decrease) in accounts payable and accrued liabilities(119)100 
Increase (decrease) in taxes payableIncrease (decrease) in taxes payable(387)187 Increase (decrease) in taxes payable22 (387)
Changes in other operating assets and liabilitiesChanges in other operating assets and liabilities(152)(51)Changes in other operating assets and liabilities(222)(152)
Net cash provided by (used in) operating activitiesNet cash provided by (used in) operating activities1,353 1,376 Net cash provided by (used in) operating activities1,612 1,353 
Cash Flows From Investing ActivitiesCash Flows From Investing ActivitiesCash Flows From Investing Activities
Additions to property, plant and equipment - E&PAdditions 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 - MidstreamAdditions to property, plant and equipment - Midstream(111)(53)Additions to property, plant and equipment - Midstream(107)(111)
Proceeds from asset sales, net of cash soldProceeds from asset sales, net of cash sold28 297 Proceeds from asset sales, net of cash sold— 28 
Other, netOther, net— (2)Other, net(4)— 
Net cash provided by (used in) investing activitiesNet 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 ActivitiesCash Flows From Financing ActivitiesCash Flows From Financing Activities
Net borrowings (repayments) of debt with maturities of 90 days or lessNet borrowings (repayments) of debt with maturities of 90 days or less(13)(75)Net borrowings (repayments) of debt with maturities of 90 days or less180 (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:
BorrowingsBorrowings400 — Borrowings— 400 
RepaymentsRepayments(510)(5)Repayments— (510)
Cash dividends paidCash dividends paid(235)(157)Cash dividends paid(271)(235)
Common stock acquired and retiredCommon stock acquired and retired(190)— Common stock acquired and retired(20)(190)
Proceeds from sale of Class A shares of Hess Midstream LPProceeds from sale of Class A shares of Hess Midstream LP146 70 Proceeds from sale of Class A shares of Hess Midstream LP167 146 
Noncontrolling interests, netNoncontrolling interests, net(351)(137)Noncontrolling interests, net(263)(351)
Employee stock options exercisedEmployee stock options exercised40 75 Employee stock options exercised40 
Payments on finance lease obligationsPayments on finance lease obligations(4)(4)Payments on finance lease obligations(4)(4)
Other, netOther, net(9)(7)Other, net(3)(9)
Net cash provided by (used in) financing activitiesNet 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 EquivalentsNet 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 YearCash and Cash Equivalents at Beginning of Year2,713 1,739 Cash and Cash Equivalents at Beginning of Year2,486 2,713 
Cash and Cash Equivalents at End of PeriodCash 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.

5


PART I - FINANCIAL INFORMATION (CONT’D.)

HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED EQUITY (UNAUDITED)
Common StockCapital in Excess of ParRetained EarningsAccumulated Other Comprehensive Income (Loss)Total Hess Stockholders' EquityNoncontrolling InterestsTotal Equity Common StockCapital in Excess of ParRetained EarningsAccumulated Other Comprehensive LossTotal Hess Stockholders' EquityNoncontrolling InterestsTotal Equity
For the Three Months Ended June 30, 2023For the Three Months Ended June 30, 2023       
Balance at April 1, 2023Balance at April 1, 2023$307 $6,254 $1,686 $(114)$8,133 $588 $8,721 
Net incomeNet income— — 119 — 119 86 205 
Other comprehensive income (loss)Other comprehensive income (loss)— — — (33)(33)— (33)
Share-based compensationShare-based compensation— 19 — — 19 — 19 
Dividends on common stockDividends on common stock— — (135)— (135)— (135)
Sale of Class A shares of Hess Midstream LPSale of Class A shares of Hess Midstream LP— 158 — — 158 93 251 
Repurchase of Class B units of Hess Midstream Operations LPRepurchase of Class B units of Hess Midstream Operations LP— 11 — — 11 (55)(44)
Noncontrolling interests, netNoncontrolling interests, net— — — — — (82)(82)
Balance at June 30, 2023Balance at June 30, 2023$307 $6,442 $1,670 $(147)$8,272 $630 $8,902 
For the Three Months Ended June 30, 2022For the Three Months Ended June 30, 2022       For the Three Months Ended June 30, 2022
Balance at April 1, 2022Balance 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 incomeNet 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 compensationShare-based compensation24 — — 25 — 25 Share-based compensation24 — — 25 — 25 
Dividends on common stockDividends on common stock— — (117)— (117)— (117)Dividends on common stock— — (117)— (117)— (117)
Sale of Class A shares of Hess Midstream LPSale 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 LPRepurchase 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 retiredCommon stock acquired and retired(2)(33)(155)— (190)— (190)Common stock acquired and retired(2)(33)(155)— (190)— (190)
Noncontrolling interests, netNoncontrolling interests, net— — — — — (78)(78)Noncontrolling interests, net— — — — — (78)(78)
Balance at June 30, 2022Balance 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, 2023For the Six Months Ended June 30, 2023
Balance at January 1, 2023Balance at January 1, 2023$306 $6,206 $1,474 $(131)$7,855 $641 $8,496 
Net incomeNet 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 compensationShare-based compensation80 — — 82 — 82 Share-based compensation59 — — 60 — 60 
Dividends on common stockDividends on common stock— — (77)— (77)— (77)Dividends on common stock— — (269)— (269)— (269)
Sale of Class A shares of Hess Midstream LPSale of Class A shares of Hess Midstream LP— 158 — — 158 93 251 
Repurchase of Class B units of Hess Midstream Operations LPRepurchase of Class B units of Hess Midstream Operations LP— 19 — — 19 (109)(90)
Noncontrolling interests, netNoncontrolling 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, 2023Balance at June 30, 2023$307 $6,442 $1,670 $(147)$8,272 $630 $8,902 
For the Six Months Ended June 30, 2022For the Six Months Ended June 30, 2022For the Six Months Ended June 30, 2022
Balance at January 1, 2022Balance 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 incomeNet 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 compensationShare-based compensation90 — — 92 — 92 Share-based compensation90 — — 92 — 92 
Dividends on common stockDividends on common stock— — (233)— (233)— (233)Dividends on common stock— — (233)— (233)— (233)
Sale of Class A shares of Hess Midstream LPSale 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 LPRepurchase 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 retiredCommon stock acquired and retired(2)(33)(155)— (190)— (190)Common stock acquired and retired(2)(33)(155)(190)— (190)
Noncontrolling interests, netNoncontrolling interests, net— — — — — (152)(152)Noncontrolling interests, net— — — — — (152)(152)
Balance at June 30, 2022Balance 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 compensation119 — — 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.


6

PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
1.  Basis of Presentation                    
The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of our consolidated financial position at June 30, 20222023 and December 31, 2021,2022, the consolidated results of operations for the three and six months ended June 30, 20222023 and 2021,2022, and consolidated cash flows for the six months ended June 30, 20222023 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 liquidsCrude oil and natural gas liquids$142 $52 Crude oil and natural gas liquids$84 $63 
Materials and suppliesMaterials and supplies175 171 Materials and supplies194 154 
Total InventoriesTotal 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, 20222023 (in millions):

Balance at January 1, 20222023$681886 
Additions to capitalized exploratory well costs pending the determination of proved reserves194128 
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, 20222023$782930 
AdditionsIn the first six months, additions to capitalized exploratory well costs pending determination of proved reserves areprimarily related to wells drilled on the Stabroek Block (Hess 30%), offshore Guyana, and drilling at the Huron prospectPickerel-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 YellowtailUaru Field development project, the fourthfifth 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 Blockblock 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 relatesrelate 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
7

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-developmentPre-development studies are ongoing.
7

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: $2,6942022: $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: $22022: $3 million), property, plant and equipment with a carrying value of $3,145$3,188 million (December 31, 2021: $3,1252022: $3,173 million) and an equity-method investment in the Little Missouri 4 (LM4) gas processing plant of $97$93 million (December 31, 2021: $1022022: $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, 20222023 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 amountvalue 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 amountvalue and tax basis of Hess Midstream LP's investment in HESM Opco. The $200 million paid to GIP reduced Noncontrolling Interestsinterests. 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 expenditures515 479 
Accrued payments to royalty and working interest owners263 253 
Current portion of asset retirement obligations232 185 
Accrued interest on debt143 138 
Accrued compensation and benefits62 124 
Other accruals18 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
8

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 covenants5.  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 expenditures400 522 
Current portion of asset retirement obligations241 207 
Accrued payments to royalty and working interest owners179 201 
Accrued interest on debt144 143 
Accrued compensation and benefits76 132 
Other accruals125 136 
Total Accrued Liabilities$1,754 $1,840 
9

7.
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 ProductionMidstreamEliminationsTotal Exploration and ProductionMidstreamEliminationsTotal
United StatesGuyanaMalaysia and JDAOther (a)E&P Total    United StatesGuyanaMalaysia and JDAOther (a)E&P Total   
Three Months Ended June 30, 2022        
Sales of our net production volumes:        
Three Months Ended June 30, 2023Three Months Ended June 30, 2023        
Sales of net production volumes:Sales of net production volumes:        
Crude oil revenueCrude oil revenue$895 $681 $37 $170 $1,783 $— $— $1,783 Crude oil revenue$710 $787 $24 $— $1,521 $— $— $1,521 
Natural gas liquids revenueNatural gas liquids revenue173 — — — 173 — — 173 Natural gas liquids revenue112 — — — 112 — — 112 
Natural gas revenueNatural gas revenue126 — 215 346 — — 346 Natural gas revenue38 — 182 — 220 — — 220 
Sales of purchased oil and gasSales of purchased oil and gas761 18 — 36 815 — — 815 Sales of purchased oil and gas469 15 — — 484 — — 484 
Intercompany revenueIntercompany revenue— — — — — 314 (314)— Intercompany revenue— — — — — 322 (322)— 
Total revenues from contracts with customers1,955 699 252 211 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)— (48)
Total sales and other operating revenuesTotal 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, 2022Three Months Ended June 30, 2022        
Sales of net production volumes:Sales of net production volumes:        
Crude oil revenueCrude oil revenue$661 $134 $27 $135 $957 $— $— $957 Crude oil revenue$895 $681 $37 $170 $1,783 $— $— $1,783 
Natural gas liquids revenueNatural gas liquids revenue120 — — — 120 — — 120 Natural gas liquids revenue173 — — — 173 — — 173 
Natural gas revenueNatural gas revenue61 — 178 240 — — 240 Natural gas revenue126 — 215 346 — — 346 
Sales of purchased oil and gasSales of purchased oil and gas299 — 26 329 — — 329 Sales of purchased oil and gas761 18 — 36 815 — — 815 
Intercompany revenueIntercompany revenue— — — — — 294 (294)— Intercompany revenue— — — — — 314 (314)— 
Total revenues from contracts with customers1,141 138 205 162 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 revenuesTotal 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, 2023Six Months Ended June 30, 2023
Sales of net production volumes:Sales of net production volumes:
Crude oil revenueCrude 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 revenueNatural gas liquids revenue354 — — — 354 — — 354 Natural gas liquids revenue253 — — — 253 — — 253 
Natural gas revenueNatural gas revenue211 — 405 10 626 — — 626 Natural gas revenue92 — 362 — 454 — — 454 
Sales of purchased oil and gasSales of purchased oil and gas1,421 22 — 71 1,514 — — 1,514 Sales of purchased oil and gas996 32 — — 1,028 — — 1,028 
Intercompany revenueIntercompany revenue— — — — — 626 (626)— Intercompany revenue— — — — — 625 (625)— 
Total revenues from contracts with customers3,717 929 473 397 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)— (79)
Total sales and other operating revenuesTotal 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, 2022Six Months Ended June 30, 2022
Sales of net production volumes:Sales of net production volumes:
Crude oil revenueCrude 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 revenueNatural gas liquids revenue263 — — — 263 — — 263 Natural gas liquids revenue354 — — — 354 — — 354 
Natural gas revenueNatural gas revenue174 — 341 519 — — 519 Natural gas revenue211 — 405 10 626 — — 626 
Sales of purchased oil and gasSales of purchased oil and gas597 — 45 650 — — 650 Sales of purchased oil and gas1,421 22 — 71 1,514 — — 1,514 
Intercompany revenueIntercompany revenue— — — — — 583 (583)— Intercompany revenue— — — — — 626 (626)— 
Total revenues from contracts with customers2,580 323 390 300 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 revenuesTotal 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 werewas sold in the third quarter of 2021.November 2022.
(b)IncludesGuyana 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
9

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 fromwere 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, 20222023 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,
 2022202120222021
(In millions)
 
Service cost$12 $13 $25 $27 
Interest cost (a)17 14 33 28 
Expected return on plan assets (a)(52)(49)(105)(99)
Amortization of unrecognized net actuarial losses (a)13 28 
Settlement loss (a)
Net periodic benefit cost (income) (a)$(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.
10

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,
 2023202220232022
(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)
Settlement loss (a)— $— $
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,
2022202120222021 2023202220232022
(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 interests87 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 incomeNet income$205 $754 $633 $1,259 
Less: Net income attributable to noncontrolling interestsLess: Net income attributable to noncontrolling interests86 87 168 175 
Net income attributable to Hess CorporationNet 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:
BasicBasic309.7 307.5 309.3 306.7 Basic306.0 309.7 305.7 309.3 
Effect of dilutive securitiesEffect of dilutive securitiesEffect of dilutive securities
Restricted common stockRestricted common stock0.6 — 0.6 0.7 Restricted common stock0.3 0.6 0.5 0.6 
Stock optionsStock options0.6 — 0.6 0.5 Stock options0.7 0.6 0.7 0.6 
Performance share unitsPerformance share units— — 0.1 0.8 Performance share units0.5 — 0.5 0.1 
DilutedDiluted310.9 307.5 310.6 308.7 Diluted307.5 310.9 307.4 310.6 
11

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,
2022202120222021 2023202220232022
Restricted common stockRestricted common stock— 1,641,860 48 94,726 Restricted common stock1,789 — 61,489 48 
Stock optionsStock options269,748 2,562,983 172,581 832,454 Stock options189,479 269,748 121,226 172,581 
Performance share unitsPerformance share units29,668 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 565,318451,226 shares of restricted stock (2021: 705,489)(2022: 565,318), 178,008130,272 performance share units (2021: 205,155)(2022: 178,008) and 269,748189,479 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
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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
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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. WhileIn February 2023, Hess, HONX, Inc., the ultimate outcomeUnsecured Creditors’ Committee, and impact to us cannot be predicted with certainty, we believe that thecounsel representing claimants, reached a mediated resolution of these proceedings will notthe matter, contingent upon final approvals of all parties and confirmation by the Bankruptcy Court. As of June 30, 2023, we have a material adverse effectprovision 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,
12

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.
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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 ProductionMidstreamCorporate, Interest and OtherEliminationsTotal
 (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 Amortization345 44 — 391 
Provision (Benefit) for Income Taxes321 — — 328 
Capital Expenditures593 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 Amortization344 41 — — 385 
Impairment and other147 — — — 147 
Provision (Benefit) for Income Taxes119 — — 122 
Capital Expenditures396 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 Amortization637 89 — 728 
Provision (Benefit) for Income Taxes513 12 — — 525 
Capital Expenditures1,136 109 — — 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 Amortization699 81 — 781 
Impairment and other147 — — — 147 
Provision (Benefit) for Income Taxes239 — — 245 
Capital Expenditures676 70 — — 746 
 Exploration and ProductionMidstreamCorporate, Interest and OtherEliminationsTotal
 (In millions)
For the Three Months Ended June 30, 2023     
Sales and other operating revenues$2,287 $$— $— $2,289 
Intersegment revenues— 322 — (322)— 
Total sales and other operating revenues$2,287 $324 $— $(322)$2,289 
Net income (loss) attributable to Hess Corporation$155 $62 $(98)$— $119 
Depreciation, depletion and amortization450 47 — — 497 
Impairment and other82 — — — 82 
Provision for income taxes152 — — 160 
Capital expenditures904 52 — — 956 
For the Three Months Ended June 30, 2022     
Sales and other operating revenues$2,955 $— $— $— $2,955 
Intersegment revenues— 314 — (314)— 
Total sales and other operating revenues$2,955 $314 $— $(314)$2,955 
Net income (loss) attributable to Hess Corporation$723 $65 $(121)$— $667 
Depreciation, depletion and amortization345 44 — 391 
Provision for income taxes321 — — 328 
Capital expenditures593 72 — — 665 
For the Six Months Ended June 30, 2023
Sales and other operating revenues$4,696 $$— $— $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 amortization893 94 — 988 
Impairment and other82 — — — 82 
Provision for income taxes322 14 — — 336 
Capital expenditures1,639 109 — — 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 amortization637 89 — 728 
Provision for income taxes513 12 — — 525 
Capital expenditures1,136 109 — — 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.

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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 ProductionExploration and Production$14,886 $14,173 Exploration and Production$15,792 $15,022 
MidstreamMidstream3,755 3,671 Midstream3,864 3,775 
Corporate, Interest and OtherCorporate, Interest and Other2,539 2,671 Corporate, Interest and Other2,574 2,898 
TotalTotal$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 reducingreduce 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 / swapsForeign exchange forwards / swaps$236 $177 
Interest rate swapsInterest rate swaps$100 $100 Interest rate swaps$100 $100 
At December 31, 2021,In the first quarter of 2023, we had hedged 90,00080,000 barrels of oil per day (bopd) with WTI collarsput options with an average monthly floor price of $60$70 per barrel, and an average monthly ceiling price of $100 per barrel and 60,00050,000 bopd with Brent collarsput 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 quarterremainder of 2022, we purchased WTI and Brent call options to remove2023.
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.

 AssetsLiabilities
 (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 instruments100 (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 contracts100 (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)
15

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.
 AssetsLiabilities
 (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 instruments26 (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 contracts31 (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— 
Total derivative contracts designated as hedging instruments157 — 
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 contracts157 (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 assetsin 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, 2022in our Consolidated Balance Sheet. The fair value of our foreign exchange forwards and swaps is presented withinOther assets at December 31, 2021Accrued 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 ($3064 million after income taxes), all of which will be reclassified into earnings during the remainder of 20222023 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.


16

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, 20222023 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.
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PART I - FINANCIAL INFORMATION (CONT'D.)
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read together with the unaudited consolidated financial statements and accompanying footnotes for the quarter ended June 30, 20222023 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.
17


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 10.212.8 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 ownHess 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.
18


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.
19


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,
2022202120222021 2023202220232022
(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 ProductionExploration and Production$723 $(25)$1,183 $283 Exploration and Production$155 $723 $560 $1,183 
MidstreamMidstream65 76 137 151 Midstream62 65 123 137 
Corporate, Interest and OtherCorporate, Interest and Other(121)(124)(236)(255)Corporate, Interest and Other(98)(121)(218)(236)
TotalTotal$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:
BasicBasic$2.15 $(0.24)$3.50 $0.58 Basic$0.39 $2.15 $1.52 $3.50 
DilutedDiluted$2.15 $(0.24)$3.49 $0.58 Diluted$0.39 $2.15 $1.51 $3.49 
Items Affecting Comparability of Earnings Between Periods
The following table summarizes, on an after-tax basis, items of income (expense) that are included in net income (loss) and affect comparability of earnings between periods: 
Three Months Ended
June 30,
Six Months Ended
June 30,
Three Months Ended
June 30,
Six Months Ended
June 30,
2022202120222021 2023202220232022
(In millions) (In millions)
Items Affecting Comparability of Earnings Between Periods, After-Tax:Items Affecting Comparability of Earnings Between Periods, After-Tax:  Items Affecting Comparability of Earnings Between Periods, After-Tax:  
Exploration and ProductionExploration and Production$— $(147)$— $(147)Exploration and Production$(82)$— $(82)$— 
MidstreamMidstream— — — — Midstream— — — — 
Corporate, Interest and OtherCorporate, Interest and Other— — 13 — Corporate, Interest and Other— — — 13 
TotalTotal$— $(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,
 2022202120222021
 (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,
 2023202220232022
 (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,
20222021 20232022
(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 activitiesNet 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 liabilitiesChanges in operating assets and liabilities1,062 98 Changes in operating assets and liabilities394 1,062 
Net cash provided by (used in) operating activities before changes in operating assets and liabilitiesNet 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,
20222021202220212023202220232022
(In millions)(In millions)
Revenues and Non-Operating IncomeRevenues and Non-Operating IncomeRevenues and Non-Operating Income
Sales and other operating revenuesSales 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, netOther, net26 14 59 30 Other, net26 22 59 
Total revenues and non-operating incomeTotal revenues and non-operating income2,981 1,593 5,327 3,507 Total revenues and non-operating income2,295 2,981 4,718 5,327 
Costs and ExpensesCosts and ExpensesCosts and Expenses
Marketing, including purchased oil and gasMarketing, including purchased oil and gas858 343 1,561 885 Marketing, including purchased oil and gas564 858 1,183 1,561 
Operating costs and expensesOperating costs and expenses291 254 542 462 Operating costs and expenses384 291 707 542 
Production and severance taxesProduction and severance taxes67 44 128 81 Production and severance taxes46 67 94 128 
Midstream tariffsMidstream tariffs296 270 583 532 Midstream tariffs302 296 585 583 
Exploration expenses, including dry holes and lease impairmentExploration expenses, including dry holes and lease impairment33 48 76 81 Exploration expenses, including dry holes and lease impairment99 33 165 76 
General and administrative expensesGeneral and administrative expenses47 49 104 98 General and administrative expenses61 47 127 104 
Depreciation, depletion and amortizationDepreciation, depletion and amortization345 344 637 699 Depreciation, depletion and amortization450 345 893 637 
Impairment and otherImpairment and other— 147 — 147 Impairment and other82 — 82 — 
Total costs and expensesTotal costs and expenses1,937 1,499 3,631 2,985 Total costs and expenses1,988 1,937 3,836 3,631 
Results of Operations Before Income TaxesResults of Operations Before Income Taxes1,044 94 1,696 522 Results of Operations Before Income Taxes307 1,044 882 1,696 
Provision (benefit) for income taxes321 119 513 239 
Net Income (Loss) Attributable to Hess Corporation$723 $(25)$1,183 $283 
Provision for income taxesProvision for income taxes152 321 322 513 
Net Income Attributable to Hess CorporationNet Income Attributable to Hess Corporation$155 $723 $560 $1,183 
TheExcluding 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:  HigherLower realized selling prices in the second quarter and first six months of 2022, increased2023 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,
2022202120222021 2023202220232022
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 StatesUnited States  United States  
North Dakota (b)$93.60 $56.75 $88.98 $49.35 
North DakotaNorth Dakota$65.67 $93.60 $67.05 $88.98 
OffshoreOffshore95.22 59.33 90.21 55.99 Offshore68.32 95.22 68.22 90.21 
Total United StatesTotal United States93.96 57.52 89.25 51.00 Total United States66.24 93.96 67.32 89.25 
GuyanaGuyana104.19 65.63 100.55 62.48 Guyana75.82 104.19 77.50 100.55 
Malaysia and JDAMalaysia and JDA106.21 65.88 97.73 64.69 Malaysia and JDA68.87 106.21 71.02 97.73 
Other (c)105.21 64.16 98.14 60.94 
Other (b)Other (b)— 105.21 — 98.14 
WorldwideWorldwide99.16 59.79 93.65 54.04 Worldwide71.13 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 StatesUnited States  United States  
North Dakota (b)$106.01 $61.88 $98.46 $52.91 
North DakotaNorth Dakota$69.22 $106.01 $70.41 $98.46 
OffshoreOffshore107.58 64.42 99.58 60.24 Offshore71.86 107.58 71.55 99.58 
Total United StatesTotal United States106.37 62.63 98.70 54.73 Total United States69.79 106.37 70.68 98.70 
GuyanaGuyana112.57 68.44 109.06 64.48 Guyana77.64 112.57 78.76 109.06 
Malaysia and JDAMalaysia and JDA106.21 65.88 97.73 64.69 Malaysia and JDA68.87 106.21 71.02 97.73 
Other (c)114.93 68.08 108.06 63.88 
Other (b)Other (b)— 114.93 — 108.06 
WorldwideWorldwide109.51 64.27 102.65 57.36 Worldwide73.74 109.51 74.87 102.65 
Natural Gas Liquids – Per BarrelNatural Gas Liquids – Per Barrel  Natural Gas Liquids – Per Barrel  
United StatesUnited States  United States  
North DakotaNorth Dakota$40.96 $23.23 $40.40 $26.65 North Dakota$17.90 $40.96 $20.99 $40.40 
OffshoreOffshore39.88 21.84 38.68 21.55 Offshore20.17 39.88 22.20 38.68 
WorldwideWorldwide40.92 23.12 40.33 26.20 Worldwide17.95 40.92 21.02 40.33 
Natural Gas – Per McfNatural Gas – Per Mcf  Natural Gas – Per Mcf  
United StatesUnited States  United States  
North DakotaNorth Dakota$6.89 $2.40 $5.57 $4.06 North Dakota$1.29 $6.89 $1.83 $5.57 
OffshoreOffshore7.63 2.35 6.02 2.66 Offshore1.62 7.63 2.03 6.02 
Total United StatesTotal United States7.06 2.38 5.67 3.56 Total United States1.35 7.06 1.87 5.67 
Malaysia and JDAMalaysia and JDA6.18 5.22 6.00 5.13 Malaysia and JDA5.56 6.18 5.50 6.00 
Other (c)5.36 2.96 5.07 2.82 
Other (b)Other (b)— 5.36 — 5.07 
WorldwideWorldwide6.45 4.05 5.87 4.47 Worldwide3.82 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 20222023 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 20222023 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 barrelsOther includes our interest in the first quarter of 2021, the North Dakota crude oil price for the first six months of 2021 excluding hedgingWaha 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 90,00080,000 bopd with WTI put options with an average monthly floor price of $60$70 per barrel, and 60,00050,000 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,
2022202120222021 2023202220232022
(In thousands) (In thousands)
Crude Oil – BarrelsCrude Oil – Barrels  Crude Oil – Barrels  
United StatesUnited States  United States  
North DakotaNorth Dakota68 79 73 82 North Dakota79 68 78 73 
OffshoreOffshore20 33 20 34 Offshore23 20 23 20 
Total United StatesTotal United States88 112 93 116 Total United States102 88 101 93 
GuyanaGuyana67 26 49 29 Guyana110 67 111 49 
Malaysia and JDAMalaysia and JDAMalaysia and JDA
Other (a)Other (a)17 24 18 23 Other (a)— 17 — 18 
TotalTotal176 166 163 172 Total216 176 216 163 
Natural Gas Liquids – BarrelsNatural Gas Liquids – Barrels  Natural Gas Liquids – Barrels  
United StatesUnited States  United States  
North DakotaNorth Dakota47 52 48 50 North Dakota68 47 64 48 
OffshoreOffshoreOffshore
Total United StatesTotal United States49 57 50 55 Total United States69 49 66 50 
Natural Gas – McfNatural Gas – Mcf  Natural Gas – Mcf  
United StatesUnited States  United States  
North DakotaNorth Dakota147 167 152 159 North Dakota206 147 182 152 
OffshoreOffshore41 85 41 90 Offshore45 41 47 41 
Total United StatesTotal United States188 252 193 249 Total United States251 188 229 193 
Malaysia and JDAMalaysia and JDA381 371 373 366 Malaysia and JDA359 381 363 373 
Other (a)Other (a)11 12 10 Other (a)— 11 — 12 
TotalTotal580 632 578 625 Total610 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 productionCrude oil and natural gas liquids as a share of total production70 %68 %69 %69 %Crude oil and natural gas liquids as a share of total production74 %70 %74 %69 %
(a)Other includes our interest in the Waha Concession in Libya, and our former interests in Denmark, which werewas sold in the third quarter of 2021.November 2022. Net production from Libya was 19,000 boepd and 20,000 boepdboped 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 335,000approximately 385,000 boepd for the third quarter and in the range of 365,000385,000 boepd to 370,000 boepd for the fourth quarter, and approximately 320,000390,000 boepd for the full year 2022.2023.
United States:  North Dakota net production was lowerhigher in the second quarter and first six months of 2022,2023, compared towith the corresponding periods in 2021, primarily2022, reflecting increased drilling and completion activity, higher NGL and natural gas volumes received under percentage of proceeds contracts due to unplanned productionlower 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 lowerhigher 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 downtimean 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 35,000Guyana included 13,000 bopd and 21,00014,000 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:  LowerHigher sales volumes in the second quarter and first six months of 2022 reduced2023 increased after-tax earnings by approximately $30$620 million and $290$1,210 million, respectively, compared towith the corresponding periods in 2021.  Worldwide2022. 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,
2022202120222021 2023202220232022
(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 – barrelsNatural gas liquids – barrels4,180 5,142 8,719 9,944 Natural gas liquids – barrels6,084 4,180 11,845 8,719 
Natural gas – mcfNatural gas – mcf52,811 57,557 104,709 113,070 Natural gas – mcf55,548 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 dayCrude oil – barrels per day173 157 157 192 Crude oil – barrels per day217 173 215 157 
Natural gas liquids – barrels per dayNatural gas liquids – barrels per day46 57 48 55 Natural gas liquids – barrels per day67 46 65 48 
Natural gas – mcf per dayNatural gas – mcf per day580 632 578 625 Natural gas – mcf per day610 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 higherlower 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 higherlower 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 20222023 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 higherlower 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 volumes2023, 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 lowerand per-unit rates were higher in the second quarter and first six months of 2022,2023, compared with the corresponding periodperiods in 2021,2022, primarily due to lowerhigher 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:
ActualForecast range (a)ActualForecast 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,
202220212022202120222022202320222023202220232023
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 13.0013.5012.5013.00DD&A (c)(b)12.79 11.79 12.97 11.39 12.5013.0013.0013.50
Total Production Unit CostsTotal 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,
2022202120222021 2023202220232022
(In millions) (In millions)
Exploratory dry hole costs (a)Exploratory dry hole costs (a)$— $$— $Exploratory dry hole costs (a)$62 $— $93 $— 
Exploration lease and other impairment10 10 
Exploration lease impairmentExploration lease impairment13 10 
Geological and geophysical expense and exploration overheadGeological and geophysical expense and exploration overhead29 33 66 62 Geological and geophysical expense and exploration overhead29 29 59 66 
Total Exploration ExpenseTotal Exploration Expense$33 $48 $76 $81 Total Exploration Expense$99 $33 $165 $76 
(a)TheExploratory dry hole costs in the second quarter 2021 dry hole costsof 2023 primarily relates to the Koebi-1Ephesus 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 $40approximately $60 million in the third quarter of 2022 and in the range of $160 million toapproximately $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 millionrespectively. 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 requirementsUnited 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 recordedrecognized a pre-tax charge of $147$82 million ($14782 million after income taxes) in connection withthat 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'sits approved bankruptcy plan.plan in 2021. See Note 8,7, Impairment and Other in the Notes toConsolidated Financial StatementsStatements.
.
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,
2022202120222021 2023202220232022
(In millions) (In millions)
Revenues and Non-Operating IncomeRevenues and Non-Operating Income  Revenues and Non-Operating Income  
Sales and other operating revenuesSales and other operating revenues$314 $294 $626 $583 Sales and other operating revenues$324 $314 $629 $626 
Other, netOther, net— Other, net— 
Total revenues and non-operating incomeTotal revenues and non-operating income314 297 627 589 Total revenues and non-operating income326 314 633 627 
Costs and ExpensesCosts and Expenses  Costs and Expenses  
Operating costs and expensesOperating costs and expenses68 64 134 124 Operating costs and expenses73 68 136 134 
General and administrative expensesGeneral and administrative expenses11 11 General and administrative expenses12 11 
Interest expenseInterest expense38 23 69 46 Interest expense44 38 86 69 
Depreciation, depletion and amortizationDepreciation, depletion and amortization44 41 89 81 Depreciation, depletion and amortization47 44 94 89 
Total costs and expensesTotal costs and expenses155 132 303 262 Total costs and expenses170 155 328 303 
Results of Operations Before Income TaxesResults of Operations Before Income Taxes159 165 324 327 Results of Operations Before Income Taxes156 159 305 324 
Provision (benefit) for income taxes12 
Net Income (Loss)152 162 312 321 
Less: Net income (loss) attributable to noncontrolling interests87 86 175 170 
Net Income (Loss) Attributable to Hess Corporation$65 $76 $137 $151 
Provision for income taxesProvision for income taxes14 12 
Net IncomeNet Income148 152 291 312 
Less: Net income attributable to noncontrolling interestsLess: Net income attributable to noncontrolling interests86 87 168 175 
Net Income Attributable to Hess CorporationNet Income Attributable to Hess Corporation$62 $65 $123 $137 
Sales and other operating revenues for the second quarter and first six months of 20222023 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 quarterthroughput 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 20222023 increased, compared towith the corresponding periodsperiod in 2021, primarily2022, 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,
2022202120222021 2023202220232022
(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 expenseInterest expense86 95 178 189 Interest expense88 86 174 178 
Less: Capitalized interestLess: Capitalized interest(3)— (3)— Less: Capitalized interest(10)(3)(15)(3)
Interest expense, netInterest expense, net83 95 175 189 Interest expense, net78 83 159 175 
Corporate, Interest and Other expenses before income taxesCorporate, Interest and Other expenses before income taxes121 124 249 255 Corporate, Interest and Other expenses before income taxes98 121 218 249 
Provision (benefit) for income taxes— — — — 
Provision for income taxesProvision for income taxes— — — — 
Net Corporate, Interest and Other expenses after income taxesNet Corporate, Interest and Other expenses after income taxes121 124 249 255 Net Corporate, Interest and Other expenses after income taxes98 121 218 249 
Items affecting comparability of earnings between periods, after-taxItems 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 taxesTotal 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 legalcapitalized 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 lowerdevelopments 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 20222023 corporate expenses are expected to be approximately $40$25 million and approximately $150in the range of $110 million to $120 million for the full year 2022.2023. Interest expense, net is expected to be approximately $85in 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 quartersix 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 debtCurrent portion of long-term debt— 517 Current portion of long-term debt
Total debt (b)Total debt (b)8,332 8,458 Total debt (b)8,467 8,281 
Total equityTotal equity7,758 7,026 Total equity8,902 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, 20222023 (December 31, 2021: $22022: $4 million) of which $2$3 million is held by Hess Midstream LP at June 30, 20222023 (December 31, 2021: $22022: $3 million).
(b)At June 30, 2022,2023, includes $2,937$3,069 million of debt outstanding from our Midstream segment (December 31, 2021: $2,5642022: $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,
20222021 20232022
(In millions) (In millions)
Net cash provided by (used in):Net cash provided by (used in):  Net cash provided by (used in):  
Operating activitiesOperating activities$1,353 $1,376 Operating activities$1,612 $1,353 
Investing activitiesInvesting activities(1,181)(445)Investing activities(1,662)(1,181)
Financing activitiesFinancing activities(726)(240)Financing activities(210)(726)
Net Increase (Decrease) in Cash and Cash EquivalentsNet Increase (Decrease) in Cash and Cash Equivalents$(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 providedflow 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 madeof approximately $470 million for previously accrued Libyan income tax and royalties of approximately $470 million for the periodat December 2020 through November31, 2021, premiums paid of $325 million to remove the ceiling price on outstanding WTI and Brentfor 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 20222023 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 saleshigher drilling activity in the first six months of 2022 were $28 million and $297 million in the first six months of 2021.Bakken.
The following table reconciles capital expenditures incurred on an accrual basis to Additions to property, plant and equipment:
Six Months Ended
June 30,
Six Months Ended
June 30,
20222021 20232022
(In millions) (In millions)
Additions to property, plant and equipment - E&P:Additions to property, plant and equipment - E&P:  Additions to property, plant and equipment - E&P:  
Capital expenditures incurred - E&PCapital expenditures incurred - E&P$(1,136)$(676)Capital expenditures incurred - E&P$(1,639)$(1,136)
Increase (decrease) in related liabilitiesIncrease (decrease) in related liabilities38 (11)Increase (decrease) in related liabilities88 38 
Additions to property, plant and equipment - E&PAdditions to property, plant and equipment - E&P$(1,098)$(687)Additions to property, plant and equipment - E&P$(1,551)$(1,098)
Additions to property, plant and equipment - Midstream:Additions to property, plant and equipment - Midstream:  Additions to property, plant and equipment - Midstream:  
Capital expenditures incurred - MidstreamCapital expenditures incurred - Midstream$(109)$(70)Capital expenditures incurred - Midstream$(109)$(109)
Increase (decrease) in related liabilitiesIncrease (decrease) in related liabilities(2)17 Increase (decrease) in related liabilities(2)
Additions to property, plant and equipment - MidstreamAdditions to property, plant and equipment - Midstream$(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 quarterNet borrowings (repayments) of 2022, we received net proceedsdebt with maturities of $146 million from the public offering of approximately 5.1 million Hess-owned Class A shares in Hess Midstream LP, and90 days or less in the first quartersix months of 2021, we received net proceeds2023 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: $1372023 (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/orand 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.
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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
CapacityBorrowingsLetters of
Credit
Issued
Total
Used
Available
Capacity
Expiration
Date
CapacityBorrowingsLetters of
Credit
Issued
Total
Used
Available
Capacity
 (In millions)  (In millions)
Hess CorporationHess Corporation      Hess Corporation      
Revolving credit facilityRevolving credit facilityMay 2024$3,500 $— $— $— $3,500 Revolving credit facilityJuly 2027$3,250 $— $— $— $3,250 
Committed linesCommitted linesVarious (a)100 — 29 29 71 Committed linesVarious (a)100 — 98 
Uncommitted linesUncommitted linesVarious (a)121 — 121 121 — Uncommitted linesVarious (a)87 — 87 87 — 
Total - Hess CorporationTotal - Hess Corporation $3,721 $— $150 $150 $3,571 Total - Hess Corporation $3,437 $— $89 $89 $3,348 
MidstreamMidstream      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 - MidstreamTotal - 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 publicsenior 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 ourthe 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 LIBORSOFR 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.
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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, 20222023 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, consolidated2023, 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 90,00080,000 bopd, and Brent put options with an average monthly floor price of $65$75 per barrel for 60,00050,000 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.

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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, 20212022 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.

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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, 20222023 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
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PART II - OTHER INFORMATION
Item 1.      Legal Proceedings.
Information regarding legal proceedings is contained in Note 11,10, Guarantees and Contingencies in the Notes to Consolidated Financial Statements and is incorporated herein by reference.
Item 2.      Share Repurchase Activities.
OurOn 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 forauthorization 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, were2023, 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:
PeriodTotal 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 
June1,753,918 108.49 1,753,918 460 
Total1,753,918 $108.49 1,753,918  
(a)Repurchasedeach term is defined in open-market transactions. The average price paid per share was inclusiveItem 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.
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PART II - OTHER INFORMATION (CONT'D)
Item 6.   Exhibits. 
Exhibits 
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.
104The 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.
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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, 20223, 2023

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