UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C.  20549
FORM 10-Q
(Mark One)
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
 For the Quarterly Period EndedJune 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 1-1513
mro_logob24.jpg
Marathon Oil Corporation
(Exact name of registrant as specified in its charter)
Delaware25-0996816
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification No.)
990 Town and Country Boulevard, Houston, Texas  
77024-2217
(Address of principal executive offices)
(713) 629-6600
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Trading SymbolName of each exchange on which registered
Common Stock, par value $1.00 MRONew 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 þ No o
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 þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 filerþAccelerated filer
o  
Non-accelerated filer
o   
Smaller reporting companyEmerging 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. o    
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes No þ  
There were 677,583,502605,687,177 shares of Marathon Oil Corporation common stock outstanding as of July 29, 2022.31, 2023.



MARATHON OIL CORPORATION
Unless the context otherwise indicates, references to “Marathon Oil,” “we,” “our,” or “us” in this Form 10-Q are references to Marathon Oil Corporation, including its wholly owned and majority-owned subsidiaries, and its ownership interests in equity method investees (corporate entities, partnerships, limited liability companies and other ventures over which Marathon Oil exerts significant influence by virtue of its ownership interest).
For certain industry specific terms used in this Form 10-Q, please see “Definitions” in our 20212022 Annual Report on Form 10-K.
 Table of Contents
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Table of Contents
Part I – FINANCIAL INFORMATION
Item 1. Financial Statements

MARATHON OIL CORPORATION
Consolidated Statements of Income (Unaudited)
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
June 30,June 30,June 30,June 30,
(In millions, except per share data)(In millions, except per share data)2022202120222021(In millions, except per share data)2023202220232022
Revenues and other income:Revenues and other income:    Revenues and other income:    
Revenues from contracts with customersRevenues from contracts with customers$2,168 $1,254 $3,929 $2,431 Revenues from contracts with customers$1,484 $2,168 $3,051 $3,929 
Net gain (loss) on commodity derivativesNet gain (loss) on commodity derivatives(27)(166)(170)(319)Net gain (loss) on commodity derivatives(27)18 (170)
Income from equity method investmentsIncome from equity method investments152 49 279 93 Income from equity method investments22 152 102 279 
Net gain (loss) on disposal of assetsNet gain (loss) on disposal of assets(1)(1)Net gain (loss) on disposal of assets— (1)(1)
Other incomeOther income11 19 Other income11 17 19 
Total revenues and other incomeTotal revenues and other income2,303 1,143 4,056 2,214 Total revenues and other income1,513 2,303 3,193 4,056 
Costs and expenses:Costs and expenses:   Costs and expenses:   
ProductionProduction164 126 316 247 Production214 164 415 316 
Shipping, handling and other operatingShipping, handling and other operating191 167 376 319 Shipping, handling and other operating161 191 323 376 
ExplorationExploration25 19 46 Exploration11 26 19 
Depreciation, depletion and amortizationDepreciation, depletion and amortization436 532 859 1,028 Depreciation, depletion and amortization559 436 1,079 859 
ImpairmentsImpairments46 47 Impairments— — 
Taxes other than incomeTaxes other than income140 74 244 148 Taxes other than income43 140 138 244 
General and administrativeGeneral and administrative68 68 141 157 General and administrative71 68 153 141 
Total costs and expensesTotal costs and expenses1,009 1,038 1,957 1,992 Total costs and expenses1,059 1,009 2,134 1,957 
Income from operationsIncome from operations1,294 105 2,099 222 Income from operations454 1,294 1,059 2,099 
Net interest and otherNet interest and other(54)(59)(76)(72)Net interest and other(92)(54)(174)(76)
Other net periodic benefit (costs) credits(1)
Loss on early extinguishment of debt— (19)— (19)
Other net periodic benefit creditsOther net periodic benefit credits
Income before income taxesIncome before income taxes1,245 26 2,032 133 Income before income taxes365 1,245 891 2,032 
Provision (benefit) for income taxesProvision (benefit) for income taxes279 10 (238)20 Provision (benefit) for income taxes78 279 187 (238)
Net incomeNet income$966 $16 $2,270 $113 Net income$287 $966 $704 $2,270 
Net income per share:Net income per share:    Net income per share:    
BasicBasic$1.37 $0.02 $3.17 $0.14 Basic$0.47 $1.37 $1.13 $3.17 
DilutedDiluted$1.37 $0.02 $3.16 $0.14 Diluted$0.47 $1.37 $1.13 $3.16 
Weighted average common shares outstanding:Weighted average common shares outstanding:    Weighted average common shares outstanding:    
BasicBasic703 789 717 790 Basic614 703 622 717 
DilutedDiluted705 789 719 791 Diluted615 705 623 719 
 The accompanying notes are an integral part of these consolidated financial statements.
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Table of Contents
MARATHON OIL CORPORATION
Consolidated Statements of Comprehensive Income (Unaudited)
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
June 30,June 30,June 30,June 30,
(In millions)(In millions)2022202120222021(In millions)2023202220232022
Net incomeNet income$966 $16 $2,270 $113 Net income$287 $966 $704 $2,270 
Other comprehensive income (loss), net of taxOther comprehensive income (loss), net of tax   Other comprehensive income (loss), net of tax   
Change in actuarial gain (loss) and other for postretirement and postemployment plansChange in actuarial gain (loss) and other for postretirement and postemployment plans16 (3)13 Change in actuarial gain (loss) and other for postretirement and postemployment plans(8)(13)(3)
Change in derivative hedges unrecognized gain (loss)(21)16 19 
Reclassification of de-designated forward interest rate swaps— (30)— (28)
Change in derivative hedges unrecognized gainChange in derivative hedges unrecognized gain16 
OtherOther(1)— (1)— Other— (1)— (1)
Other comprehensive income (loss)Other comprehensive income (loss)(35)12 Other comprehensive income (loss)(5)(12)12 
Comprehensive income (loss)$970 $(19)$2,282 $117 
Comprehensive incomeComprehensive income$282 $970 $692 $2,282 
 The accompanying notes are an integral part of these consolidated financial statements.

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Table of Contents
MARATHON OIL CORPORATION
Consolidated Balance Sheets (Unaudited)
June 30,December 31,June 30,December 31,
(In millions, except par value and share amounts)(In millions, except par value and share amounts)20222021(In millions, except par value and share amounts)20232022
AssetsAssets  Assets  
Current assets:Current assets:  Current assets:  
Cash and cash equivalentsCash and cash equivalents$1,162 $580 Cash and cash equivalents$215 $334 
Receivables, netReceivables, net1,512 1,142 Receivables, net1,294 1,146 
InventoriesInventories93 77 Inventories136 125 
Other current assetsOther current assets41 22 Other current assets58 66 
Total current assetsTotal current assets2,808 1,821 Total current assets1,703 1,671 
Equity method investmentsEquity method investments528 450 Equity method investments430 577 
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $23,116 and $22,41214,357 14,499 
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $24,888 and $23,876Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $24,888 and $23,87617,524 17,377 
Deferred tax assets325 — 
Other noncurrent assetsOther noncurrent assets268 224 Other noncurrent assets262 315 
Total assetsTotal assets$18,286 $16,994 Total assets$19,919 $19,940 
LiabilitiesLiabilities  Liabilities  
Current liabilities:Current liabilities:  Current liabilities:  
Accounts payableAccounts payable$1,523 $1,110 Accounts payable$1,537 $1,279 
Payroll and benefits payablePayroll and benefits payable50 74 Payroll and benefits payable50 90 
Accrued taxesAccrued taxes143 157 Accrued taxes102 171 
Other current liabilitiesOther current liabilities388 260 Other current liabilities305 364 
Long-term debt due within one yearLong-term debt due within one year273 36 Long-term debt due within one year131 402 
Total current liabilitiesTotal current liabilities2,377 1,637 Total current liabilities2,125 2,306 
Long-term debtLong-term debt3,709 3,978 Long-term debt5,724 5,521 
Deferred tax liabilitiesDeferred tax liabilities146 136 Deferred tax liabilities278 167 
Defined benefit postretirement plan obligationsDefined benefit postretirement plan obligations124 137 Defined benefit postretirement plan obligations105 100 
Asset retirement obligationsAsset retirement obligations278 288 Asset retirement obligations299 295 
Deferred credits and other liabilitiesDeferred credits and other liabilities120 132 Deferred credits and other liabilities144 154 
Total liabilitiesTotal liabilities6,754 6,308 Total liabilities8,675 8,543 
Commitments and contingencies00
Commitments and contingencies (Note 21)Commitments and contingencies (Note 21)
Stockholders’ EquityStockholders’ Equity  Stockholders’ Equity  
Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)— — Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)— — 
Common stock:Common stock:  Common stock:  
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at June 30, 2022 and December 31, 2021)937 937 
Held in treasury, at cost – 248 million shares and 194 million shares(6,118)(4,825)
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at June 30, 2023 and December 31, 2022)Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at June 30, 2023 and December 31, 2022)937 937 
Held in treasury, at cost – 331 million shares and 304 million sharesHeld in treasury, at cost – 331 million shares and 304 million shares(8,188)(7,512)
Additional paid-in capitalAdditional paid-in capital7,186 7,221 Additional paid-in capital7,159 7,203 
Retained earningsRetained earnings9,433 7,271 Retained earnings11,242 10,663 
Accumulated other comprehensive incomeAccumulated other comprehensive income94 82 Accumulated other comprehensive income94 106 
Total stockholders’ equityTotal stockholders’ equity11,532 10,686 Total stockholders’ equity11,244 11,397 
Total liabilities and stockholders’ equityTotal liabilities and stockholders’ equity$18,286 $16,994 Total liabilities and stockholders’ equity$19,919 $19,940 
 The accompanying notes are an integral part of these consolidated financial statements.
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MARATHON OIL CORPORATION
Consolidated Statements of Cash Flows (Unaudited)
Six Months EndedSix Months Ended
June 30,June 30,
(In millions)(In millions)20222021(In millions)20232022
Increase (decrease) in cash and cash equivalentsIncrease (decrease) in cash and cash equivalents  Increase (decrease) in cash and cash equivalents  
Operating activities:Operating activities:  Operating activities:  
Net incomeNet income$2,270 $113 Net income$704 $2,270 
Adjustments to reconcile net income to net cash provided by operating activities:Adjustments to reconcile net income to net cash provided by operating activities:  Adjustments to reconcile net income to net cash provided by operating activities:  
Depreciation, depletion and amortizationDepreciation, depletion and amortization859 1,028 Depreciation, depletion and amortization1,079 859 
ImpairmentsImpairments47 Impairments— 
Exploratory dry well costs and unproved property impairmentsExploratory dry well costs and unproved property impairments14 39 Exploratory dry well costs and unproved property impairments24 14 
Net (gain) loss on disposal of assetsNet (gain) loss on disposal of assets(1)Net (gain) loss on disposal of assets(5)
Loss on early extinguishment of debt— 19 
Deferred income taxesDeferred income taxes(319)(7)Deferred income taxes155 (319)
Unrealized loss on derivative instruments, netUnrealized loss on derivative instruments, net71 157 Unrealized loss on derivative instruments, net71 
Pension and other post retirement benefits, netPension and other post retirement benefits, net(16)(14)Pension and other post retirement benefits, net(11)(16)
Stock-based compensationStock-based compensation18 17 Stock-based compensation21 18 
Equity method investments, netEquity method investments, net(85)(17)Equity method investments, net113 (85)
Changes in:Changes in: Changes in: 
Current receivablesCurrent receivables(376)(253)Current receivables(158)(376)
InventoriesInventories(16)(2)Inventories(11)(16)
Current accounts payable and accrued liabilitiesCurrent accounts payable and accrued liabilities278 121 Current accounts payable and accrued liabilities37 278 
Other current assets and liabilitiesOther current assets and liabilities(7)73 Other current assets and liabilities10 (7)
All other operating, netAll other operating, net51 (43)All other operating, net(19)51 
Net cash provided by operating activitiesNet cash provided by operating activities2,745 1,277 Net cash provided by operating activities1,941 2,745 
Investing activities:Investing activities:  Investing activities:  
Additions to property, plant and equipmentAdditions to property, plant and equipment(687)(483)Additions to property, plant and equipment(1,166)(687)
Acquisitions, net of cash acquiredAcquisitions, net of cash acquired— Acquisitions, net of cash acquired
Disposal of assets, net of cash transferred to the buyerDisposal of assets, net of cash transferred to the buyer15 Disposal of assets, net of cash transferred to the buyer(1)
Equity method investments - return of capitalEquity method investments - return of capitalEquity method investments - return of capital34 
All other investing, netAll other investing, net— (1)All other investing, net(1)— 
Net cash used in investing activitiesNet cash used in investing activities(674)(463)Net cash used in investing activities(1,125)(674)
Financing activities:Financing activities:  Financing activities:  
Proceeds from revolving credit facilityProceeds from revolving credit facility980 — 
Repayments of revolving credit facilityRepayments of revolving credit facility(980)— 
BorrowingsBorrowings200 — 
Debt repaymentsDebt repayments(270)(32)
Debt repayment(32)(500)
Debt extinguishment costs— (19)
Shares repurchased under buyback programsShares repurchased under buyback programs(1,352)— Shares repurchased under buyback programs(706)(1,352)
Dividends paidDividends paid(108)(55)Dividends paid(125)(108)
Purchases of shares for tax withholding obligationsPurchases of shares for tax withholding obligations(21)(9)Purchases of shares for tax withholding obligations(30)(21)
All other financing, netAll other financing, net24 (3)All other financing, net(4)24 
Net cash used in financing activitiesNet cash used in financing activities(1,489)(586)Net cash used in financing activities(935)(1,489)
Net increase in cash and cash equivalents582 228 
Net increase (decrease) in cash and cash equivalentsNet increase (decrease) in cash and cash equivalents(119)582 
Cash and cash equivalents at beginning of periodCash and cash equivalents at beginning of period580 742 Cash and cash equivalents at beginning of period334 580 
Cash and cash equivalents at end of periodCash and cash equivalents at end of period$1,162 $970 Cash and cash equivalents at end of period$215 $1,162 
The accompanying notes are an integral part of these consolidated financial statements.
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MARATHON OIL CORPORATION
Consolidated Statements of Stockholders’ Equity (Unaudited)
Total Equity of Marathon Oil Stockholders Total Equity of Marathon Oil Stockholders
(In millions)(In millions)Preferred
Stock
Common
Stock
Treasury
Stock
Additional
Paid-in
Capital
Retained
Earnings
Accumulated
Other
Comprehensive
Income (Loss)
Total
Equity
(In millions)Preferred
Stock
Common
Stock
Treasury
Stock
Additional
Paid-in
Capital
Retained
Earnings
Accumulated
Other
Comprehensive
Income
Total
Equity
Six Months Ended June 30, 2021
December 31, 2020 Balance$— $937 $(4,089)$7,174 $6,466 $73 $10,561 
Shares repurchased under buyback programs— — — — — — — 
Stock-based compensation— — (24)21 — — (3)
Net income (loss)— — — — 97 — 97 
Other comprehensive income (loss)— — — — — 39 39 
Dividends paid (per share amount of $0.03)— — — — (23)— (23)
March 31, 2021 Balance$— $937 $(4,113)$7,195 $6,540 $112 $10,671 
Shares repurchased under buyback programs— — — — — — — 
Stock-based compensation— — — — 14 
Net income (loss)— — — — 16 — 16 
Other comprehensive income (loss)— — — — — (35)(35)
Dividends paid (per share amount of $0.04)— — — — (32)— (32)
June 30, 2021 Balance$— $937 $(4,105)$7,201 $6,524 $77 $10,634 
Six Months Ended June 30, 2022Six Months Ended June 30, 2022Six Months Ended June 30, 2022
December 31, 2021 BalanceDecember 31, 2021 Balance$— $937 $(4,825)$7,221 $7,271 $82 $10,686 December 31, 2021 Balance$— $937 $(4,825)$7,221 $7,271 $82 $10,686 
Shares repurchased under buyback programsShares repurchased under buyback programs— — (592)— — — (592)Shares repurchased under buyback programs— — (592)— — — (592)
Stock-based compensationStock-based compensation— — 55 (43)— — 12 Stock-based compensation— — 55 (43)— — 12 
Net income (loss)— — — — 1,304 — 1,304 
Other comprehensive income (loss)— — — — — 
Net incomeNet income— — — — 1,304 — 1,304 
Other comprehensive incomeOther comprehensive income— — — — — 
Dividends paid (per share amount of $0.07) Dividends paid (per share amount of $0.07)— — — — (52)— (52)Dividends paid (per share amount of $0.07)— — — — (52)— (52)
March 31, 2022 BalanceMarch 31, 2022 Balance$— $937 $(5,362)$7,178 $8,523 $90 $11,366 March 31, 2022 Balance$— $937 $(5,362)$7,178 $8,523 $90 $11,366 
Shares repurchased under buyback programsShares repurchased under buyback programs— — (760)— — — (760)Shares repurchased under buyback programs— — (760)— — — (760)
Stock-based compensationStock-based compensation— — — — 12 Stock-based compensation— — — — 12 
Net incomeNet income— — — — 966 — 966 Net income— — — — 966 — 966 
Other comprehensive incomeOther comprehensive income— — — — — Other comprehensive income— — — — — 
Dividends paid (per share amount of $0.08) Dividends paid (per share amount of $0.08)— — — — (56)— (56)Dividends paid (per share amount of $0.08)— — — — (56)— (56)
June 30, 2022 BalanceJune 30, 2022 Balance$— $937 $(6,118)$7,186 $9,433 $94 $11,532 June 30, 2022 Balance$— $937 $(6,118)$7,186 $9,433 $94 $11,532 
Six Months Ended June 30, 2023Six Months Ended June 30, 2023
December 31, 2022 BalanceDecember 31, 2022 Balance$— $937 $(7,512)$7,203 $10,663 $106 $11,397 
Shares repurchased under buyback programsShares repurchased under buyback programs— — (334)— — — (334)
Excise tax on shares repurchasedExcise tax on shares repurchased— — (3)— — — (3)
Stock-based compensationStock-based compensation— — 35 (54)— — (19)
Net incomeNet income— — — — 417 — 417 
Other comprehensive lossOther comprehensive loss— — — — — (7)(7)
Dividends paid (per share amount of $0.10)Dividends paid (per share amount of $0.10)— — — — (63)— (63)
March 31, 2023 BalanceMarch 31, 2023 Balance$— $937 $(7,814)$7,149 $11,017 $99 $11,388 
Shares repurchased under buyback programsShares repurchased under buyback programs— — (372)— — — (372)
Excise tax on shares repurchasedExcise tax on shares repurchased— — (3)— — — (3)
Stock-based compensationStock-based compensation— — 10 — — 11 
Net incomeNet income— — — — 287 — 287 
Other comprehensive lossOther comprehensive loss— — — — — (5)(5)
Dividends paid (per share amount of $0.10)Dividends paid (per share amount of $0.10)— — — — (62)— (62)
June 30, 2023 BalanceJune 30, 2023 Balance$— $937 $(8,188)$7,159 $11,242 $94 $11,244 
The accompanying notes are an integral part of these consolidated financial statements.





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Table of Contents
MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


1.    Basis of Presentation
These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements.
These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our 20212022 Annual Report on Form 10-K. The results of operations for the second quarter and first six months of 20222023 are not necessarily indicative of the results to be expected for the full year.
2.    Accounting Standards
Accounting Standards Updates Adopted
No accounting standards were adopted in the second quarter or first six months of 20222023 that had a material impact on our consolidated financial statements.
Accounting Standards Updates Not Yet Adopted
There were no issued but pending accounting standards expected to have a material impact on our consolidated financial statements.
3.    Income and Dividends per Common Share
Basic income per share is based on the weighted average number of common shares outstanding. Diluted income per share assumes exercise of stock options in all periods, provided the effect is not antidilutive. The per share calculations below exclude 1 million of antidilutive stock options for the three and six months ended June 30, 2023 and 2 million of antidilutive stock options for the three and six months ended June 30, 2022, and 4 million and 5 million of stock options for the three and six months ended June 30, 2021, respectively, that were antidilutive.respectively.

Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
(In millions, except per share data)(In millions, except per share data)2022202120222021(In millions, except per share data)2023202220232022
Net incomeNet income$966 $16 $2,270 $113 Net income$287 $966 $704 $2,270 
Weighted average common shares outstandingWeighted average common shares outstanding703 789 717 790 Weighted average common shares outstanding614 703 622 717 
Effect of dilutive securitiesEffect of dilutive securities— Effect of dilutive securities
Weighted average common shares, dilutedWeighted average common shares, diluted705 789 719 791 Weighted average common shares, diluted615 705 623 719 
Net income per share:Net income per share:Net income per share:
BasicBasic$1.37 $0.02 $3.17 $0.14 Basic$0.47 $1.37 $1.13 $3.17 
DilutedDiluted$1.37 $0.02 $3.16 $0.14 Diluted$0.47 $1.37 $1.13 $3.16 
Dividends per shareDividends per share$0.08 $0.04 $0.15 $0.07 Dividends per share$0.10 $0.08 $0.20 $0.15 
4.    Revenues
The majority of our revenues are derived from the sale of crude oil and condensate, NGLs and natural gas under spot and term agreements with our customers in the United States and Equatorial Guinea.
As of June 30, 20222023 and December 31, 2021,2022, receivables from contracts with customers, included in receivables, netless reserves for credit losses, were $1.3 billion$892 million and $961$875 million, respectively.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas for the three and six months ended June 30:
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United States
Three Months Ended June 30, 2022
(In millions)Eagle FordBakkenOklahomaNorthern DelawareOther U.S.Total
Crude oil and condensate$544 $749 $138 $100 $42 $1,573 
Natural gas liquids55 92 69 15 239 
Natural gas56 46 95 21 10 228 
Other— — — 48 49 
Revenues from contracts with customers$656 $887 $302 $136 $108 $2,089 
Three Months Ended June 30, 2021
(In millions)Eagle FordBakkenOklahomaNorthern DelawareOther U.S.Total
Crude oil and condensate$353 $411 $71 $77 $24 $936 
Natural gas liquids33 48 37 11 131 
Natural gas29 17 41 (1)91 
Other— — — 29 31 
Revenues from contracts with customers$417 $476 $149 $93 $54 $1,189 
Six Months Ended June 30, 2022
(In millions)Eagle FordBakkenOklahomaNorthern DelawareOther U.S.Total
Crude oil and condensate$1,003 $1,401 $237 $188 $85 $2,914 
Natural gas liquids99 181 128 30 17 455 
Natural gas89 89 151 33 17 379 
Other— — — 52 55 
Revenues from contracts with customers$1,194 $1,671 $516 $251 $171 $3,803 
Six Months Ended June 30, 2021
(In millions)Eagle FordBakkenOklahomaNorthern DelawareOther U.S.Total
Crude oil and condensate$612 $783 $132 $154 $46 $1,727 
Natural gas liquids59 89 74 20 247 
Natural gas76 42 150 30 306 
Other— — — 37 41 
Revenues from contracts with customers$751 $914 $356 $204 $96 $2,321 

International (E.G.)
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2022202120222021
Crude oil and condensate$71 $58 $111 $95 
Natural gas liquids— 
Natural gas12 12 
Other
Revenues from contracts with customers$79 $65 $126 $110 
8

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


United States
Three Months Ended June 30, 2023
(In millions)Eagle FordBakkenOklahomaPermianOther U.S.Total
Crude oil and condensate$524 $456 $63 $141 $11 $1,195 
Natural gas liquids64 41 33 18 — 156 
Natural gas37 14 28 — 86 
Other— — — 
Revenues from contracts with customers$626 $511 $124 $166 $13 $1,440 
Three Months Ended June 30, 2022
(In millions)Eagle FordBakkenOklahomaPermianOther U.S.Total
Crude oil and condensate$544 $749 $138 $100 $42 $1,573 
Natural gas liquids55 92 69 15 239 
Natural gas56 46 95 21 10 228 
Other— — — 48 49 
Revenues from contracts with customers$656 $887 $302 $136 $108 $2,089 
Six Months Ended June 30, 2023
(In millions)Eagle FordBakkenOklahomaPermianOther U.S.Total
Crude oil and condensate$1,019 $887 $141 $311 $22 $2,380 
Natural gas liquids135 78 72 40 — 325 
Natural gas93 49 64 18 225 
Other— — — 10 13 
Revenues from contracts with customers$1,250 $1,014 $277 $369 $33 $2,943 
Six Months Ended June 30, 2022
(In millions)Eagle FordBakkenOklahomaPermianOther U.S.Total
Crude oil and condensate$1,003 $1,401 $237 $188 $85 $2,914 
Natural gas liquids99 181 128 30 17 455 
Natural gas89 89 151 33 17 379 
Other— — — 52 55 
Revenues from contracts with customers$1,194 $1,671 $516 $251 $171 $3,803 
International (E.G.)
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2023202220232022
Crude oil and condensate$39 $71 $96 $111 
Natural gas liquids— — 
Natural gas12 
Other
Revenues from contracts with customers$44 $79 $108 $126 
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


5.    Segment Information
We have 2two reportable operating segments. Both of these segments are organized and managed based upon geographic location and the nature of the products and services offered.
United States (“U.S.”) – explores for, produces and markets crude oil and condensate, NGLs and natural gas in the United StatesStates; and
International (“Int’l”) – explores for, produces and markets crude oil and condensate, NGLs and natural gas outside of the United States as well as produces and markets products manufactured from natural gas, such as LNG and methanol, in Equatorial Guinea (“E.G.”)
Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs are not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, goodwill and equity method investments,dry wells, changes in our valuation allowance, unrealized gains or losses on commodity and interest rate derivative instruments, effects of pension settlements and curtailments, expensed transaction costs for business combinations or other items (as determined by the chief operating decision maker (“CODM”)) are not allocated to operating segments.
 Three Months Ended June 30, 2023
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenues from contracts with customers$1,440 $44 $— $1,484 
Net gain (loss) on commodity derivatives— (4)(c)
Income from equity method investments— 22 — 22 
Other income— 
Less costs and expenses:
Production191 23 — 214 
Shipping, handling and other operating161 — — 

161 
Exploration— 

11 
Depreciation, depletion and amortization547 10 559 
Taxes other than income43 (b)— — 43 
General and administrative31 37 71 
Net interest and other— — 92 92 
Other net periodic benefit costs— — (3)

(3)
Income tax provision (benefit)104 (29)78 
Segment income (loss)$365 $30 $(108)$287 
Total assets$18,761 $1,006 $152 $19,919 
Capital expenditures(a)
$620 $— $$623 
(a)Includes accruals and excludes acquisitions.
(b)Includes a nonrecurring Eagle Ford severance tax refund of $47 million related to prior years.
(c)Unrealized loss on commodity derivative instruments (See Note 12).




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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


 Three Months Ended June 30, 2022
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenues from contracts with customers$2,089 $79 $— $2,168 
Net gain (loss) on commodity derivatives(70)— 43 (b)(27)
Income from equity method investments— 152 — 152 
Net loss on disposal of assets— — (1)(1)
Other income11 
Less costs and expenses:
Production150 14 — 164 
Shipping, handling and other operating187 191 
Exploration— — 
Depreciation, depletion and amortization415 16 436 
Impairments— — 
Taxes other than income139 — 140 
General and administrative27 38 

68 
Net interest and other— — 54 54 
Other net periodic benefit costs— — (5)(5)
Income tax provision (benefit)249 39 (9)279 
Segment income (loss)$846 $160 $(40)$966 
Total assets$15,757 $1,059 $1,470 $18,286 
Capital expenditures(a)
$372 $$$375 
(a)Includes accruals.
(b)Unrealized gain on commodity derivative instruments (See Note 1312).

9

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
 Three Months Ended June 30, 2021
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenues from contracts with customers$1,189 $65 $— $1,254 
Net gain (loss) on commodity derivatives(91)— (75)(b)(166)
Income (loss) from equity method investments— 49 — 49 
Net gain on disposal of assets— — 
Other income— 
Less costs and expenses:
Production113 13 — 126 
Shipping, handling and other operating153 12 167 
Exploration18 — 25 
Depreciation, depletion and amortization506 18 532 
Impairments— — 46 (c)46 
Taxes other than income76 — (2)74 
General and administrative27 37 

68 
Net interest and other— — 59 (d)59 
Other net periodic benefit costs— — 
Loss on early extinguishment of debt— — 19 (e)19 
Income tax provision (benefit)11 (2)10 
Segment income (loss)$207 $68 $(259)$16 
Total assets$15,747 $1,047 $1,006 $17,800 
Capital expenditures(a)
$284 $$$289 
(a)Includes accruals.
(b)Unrealized loss on commodity derivative instruments (See Note 13).
(c)Includes impairments of $24 million associated with central facilities in Eagle Ford (See Note 10) and $22 million associated with decommissioning costs for non-producing long-lived assets in the Gulf of Mexico (‘GOM’) (See Note 10, Note 11 and Note 22).
(d)Includes a $22 million loss on 2022 interest rate swaps and a $31 million gain on 2025 interest rate swaps, neither of which were designated as cash flow hedges as of June 30, 2021 (See Note 13).
(e)Represents costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs related to the redemption of the 2022 Notes in April 2021.










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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)

 Six Months Ended June 30, 2022
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenues from contracts with customers$3,803 $126 $— $3,929 
Net loss on commodity derivatives(99)— (71)(b)(170)
Income from equity method investments— 279 — 279 
Net loss on disposal of assets— — (1)(1)
Other income19 
Less costs and expenses:
Production291 25 — 316 
Shipping, handling and other operating337 10 29 376 
Exploration19 — — 

19 
Depreciation, depletion and amortization819 31 859 
Impairments— — 

Taxes other than income238 — 244 
General and administrative57 78 

141 
Net interest and other— — 76 (c)76 
Other net periodic benefit credit— — (9)(9)
Income tax provision (benefit)442 62 (742)(d)(238)
Segment income$1,507 $275 $488 $2,270 
Total assets$15,757 $1,059 $1,470 $18,286 
Capital expenditures(a)
$718 $— $$723 

 Six Months Ended June 30, 2023
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenues from contracts with customers$2,943 $108 $— $3,051 
Net gain (loss) on commodity derivatives20 — (2)(c)18 
Income from equity method investments— 102 — 102 
Net gain on disposal of assets— — 
Other income12 17 
Less costs and expenses:
Production369 46 — 415 
Shipping, handling and other operating320 — 323 
Exploration11 — 15 (d)26 
Depreciation, depletion and amortization1,052 22 1,079 
Taxes other than income140 (b)— (2)138 
General and administrative66 81 

153 
Net interest and other— — 174 

174 
Other net periodic benefit costs— — (6)(6)
Income tax provision (benefit)227 18 (58)

187 
Segment income (loss)$790 $119 $(205)$704 
Total assets$18,761 $1,006 $152 $19,919 
Capital expenditures(a)
$1,217 $$$1,224 
(a)Includes accruals.
(b)Includes a nonrecurring Eagle Ford severance tax refund of $47 million related to prior years.
(c)Unrealized loss on commodity derivative instruments (SeeNote 12).
(d)Includes $10 million of dry well expense associated with wells in Permian (See Note 9).

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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


Six Months Ended June 30, 2022
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenue from contracts with customers$3,803 $126 $— $3,929 
Net loss on commodity derivatives(99)— (71)(b)(170)
Income from equity method investments— 279 — 

279 
Net loss on disposal of assets— — (1)(1)
Other income19 
Less costs and expenses:
Production291 25 — 316 
Shipping, handling and other operating337 10 29 376 
Exploration19 — — 19 
Depreciation, depletion and amortization819 31 859 
Impairments— — 
Taxes other than income238 — 244 
General and administrative57 78 141 
Net interest and other— — 76 (c)76 
Other net periodic benefit credit— — (9)

(9)
Income tax provision (benefit)442 62 (742)(d)(238)
Segment income$1,507 $275 $488 $2,270 
Total assets$15,757 $1,059 $1,470 $18,286 
Capital expenditures(a)
$718 $— $$723 
(a)Includes accruals.
(b)Unrealized loss on commodity derivative instruments (See Note 1412).
(c)Includes a $17 million gain on 2025 interest rate swaps (See Note 1312).
(d)Includes a $685 million benefit related to the partial release of our valuation allowance (See Note 6).

11

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
Six Months Ended June 30, 2021
(In millions)U.S.Int’lNot Allocated to SegmentsTotal
Revenue from contracts with customers$2,321 $110 $— $2,431 
Net gain on commodity derivatives(162)— (157)(b)(319)
Loss from equity method investments— 93 — 

93 
Net gain on disposal of assets— — 
Other income
Less costs and expenses:
Production224 23 — 247 
Shipping, handling and other operating297 16 319 
Exploration39 — 46 
Depreciation, depletion and amortization978 37 13 1,028 
Impairments— — 47 (c)47 
Taxes other than income150 — (2)148 
General and administrative50 101 (d)157 
Net interest and other— — 72 (e)72 
Other net periodic benefit credit— — (2)

(2)
Loss on early extinguishment of debt— — 19 (f)19 
Income tax provision (benefit)16 (2)20 
Segment income (loss)$419 $118 $(424)$113 
Total assets$15,747 $1,047 $1,006 $17,800 
Capital expenditures(a)
$467 $$$473 
(a)Includes accruals.
(b)Unrealized loss on commodity derivative instruments (SeeNote 14).
(c)Includes second quarter 2021 impairments of $24 million associated with central facilities in Eagle Ford (See Note 10) and $22 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 10, Note 11 and Note 22).
(d)Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction.
(e)Includes a $19 million gain on 2022 interest rate swaps and a $31 million gain on 2025 interest rate swaps, neither of which were designated as cash flow hedges as of June 30, 2021 (See Note 13).
(f)Represents costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs related to the redemption of the 2022 Notes in April 2021.


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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


6.    Income Taxes
Effective Tax Rate
The effective income tax rate is influenced by a variety of factors including the geographic and functional sources of income and the relative magnitude of these sources of income. The difference between the total provision and the sum of the amounts allocated to segments is reported in the “Not Allocated to Segments” column of the tables in Note 5.
For the three and six months ended June 30, 20222023 and 2021,2022, our effective income tax rates were as follows:
Three Months Ended June 30,Six Months Ended June 30,
2022202120222021
Effective income tax rate22 %38 %(12)%15 %

Three Months Ended June 30,Six Months Ended June 30,
2023202220232022
Effective income tax rate21 %22 %21 %(12)%
2022 Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the six months ended June 30, 2022, due to the first quarter 2022 release of the valuation allowance on certain U.S. and state deferred tax assets resulting in a non-cash deferred tax benefit of $685 million.
In August 2022, the President signed the Inflation Reduction Act of 2022 (“IRA”) into law. The IRA enacted various income tax provisions, including a 15% corporate book minimum tax. The corporate book minimum tax, which became effective on January 1, 2023, applies to corporations with an average annual adjusted financial statement income that exceeds $1 billion for the preceding three years. Under current law and guidance, we do not anticipate being subject to the corporate book minimum tax in 2023. The U.S. Treasury is expected to publish further guidance and regulations that will be relevant to scoping considerations and the calculation of minimum income tax liabilities. As this guidance is issued, we previously disclosed in our 2021 Form 10-K, we maintained a full valuation allowancewill continue to evaluate and assess the impact the IRA may have on our net federalcurrent and future period income taxes. We have made an accounting policy election to consider the effects of the corporate book minimum tax on the realizability of our deferred tax assets, carryforwards and would continue to do so until there exists sufficient positive evidence to support a reversal of the allowance. In the first quarter,tax credits as a result of significant increases in commodity prices, corresponding increases in projections of our future taxable income, and the absence of objective negative evidence such as a cumulative loss in recent years, we determined we have sufficient positive evidence to release a majority of the federal valuation allowance. We retained a partial valuation allowance on certain U.S. deferred tax assets primarily as a result of volatility in commodity prices impacting assessed likelihood of future realizability.
2021Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the three and six months ended June 30, 2021, as a result of the valuation allowance on net federal deferred tax assets in the U.S. which was in place at the time. In addition, the income mix of our U.S. and E.G. operations, including the income mix within E.G. between equity method investees and subsidiaries, contributed to the difference.period cost when they arise.
7.    Credit Losses
The majority of our receivables are from purchasers of commodities or joint interest owners in properties we operate, both of which are recorded at estimated or invoiced amounts and do not bear interest. The majority of these receivables have payment terms of 30 days or less. At the end of each reporting period, we assess the collectability of our receivables and estimate the expected credit losses using historical data, current market conditions, reasonable and supportable forecasts of future economic conditions and other data as deemed appropriate.
Changes in the allowance for doubtful accounts balancecredit losses were as follows:    
(In millions)(In millions)June 30, 2022December 31, 2021(In millions)June 30, 2023December 31, 2022
Beginning balance as of January 1Beginning balance as of January 1$15 $22 Beginning balance as of January 1$10 $15 
Current period provisionCurrent period provision(2)Current period provision(3)
Current period write offsCurrent period write offs— (5)Current period write offs(1)(2)
Recoveries of amounts previously reservedRecoveries of amounts previously reserved— (5)Recoveries of amounts previously reserved(1)— 
Ending balanceEnding balance$13 $15 Ending balance$12 $10 
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


8.    Inventories
Crude oil and natural gas liquids are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment which are valued at weighted average cost and reviewed periodically for obsolescence or impairment when market conditions indicate.
(In millions)(In millions)June 30, 2022December 31, 2021(In millions)June 30, 2023December 31, 2022
Crude oil and natural gas$15 $
Crude oil and natural gas liquidsCrude oil and natural gas liquids$13 $15 
Supplies and other itemsSupplies and other items78 69 Supplies and other items123 110 
InventoriesInventories$93 $77 Inventories$136 $125 
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
9.    Property, Plant and Equipment
(In millions)(In millions)June 30, 2022December 31, 2021(In millions)June 30, 2023December 31, 2022
United StatesUnited States$13,989 $14,097 United States$17,201 $17,034 
InternationalInternational315 347 International269 288 
CorporateCorporate53 55 Corporate54 55 
Net property, plant and equipmentNet property, plant and equipment$14,357 $14,499 Net property, plant and equipment$17,524 $17,377 
As of June 30, 20222023 and December 31, 2021,2022, we had $34$10 million and $80$20 million,, respectively, of exploratoryexploratory well costs capitalized greater than one year related to suspended wells. Management believes these wells exhibit sufficient quantities of hydrocarbons to justify potential development. The vast majorityAll of the suspended wells require completion activities and installation of infrastructure in order to classify the reserves as proved.
10.    Impairments
The following table summarizes impairment charges of proved properties and their corresponding fair values.
 Three Months Ended June 30,
 20222021
(In millions)Fair ValueImpairmentFair ValueImpairment
Long-lived assets held for use$— $— $— $24 
Asset retirement costs of long-lived assets$— $$— $22 

 Six Months Ended June 30,
 20222021
(In millions)Fair ValueImpairmentFair ValueImpairment
Long-lived assets held for use$— $— $— $25 
Asset retirement costs of long-lived assets$— $$— $22 
2021Duringdecrease during the second quarter of 2021,six months ended June 30, 2023 included a reduction in suspended well costs as we recorded an impairment expense of $24 million associated with 2 central facilities located in Eagle Ford. Decommissioning activities commenced during the quarter, which included the re-routing of existing wells.
We also recognized an incremental $22$10 million of impairmentdry well expense associated with an increasedrilled and uncompleted exploratory wells in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico. In a prior reporting period, we recorded a $7 million liability in our consolidated balance sheet associated with these assets, thereby increasing the total recognized asset retirement obligation to $29 million as of June 30, 2021. See Note 11 and Note 22 for further information.
The combined effects of these items were recorded within the Impairments line item within our consolidated statements of income.
14
Permian.

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
11.10.    Asset Retirement Obligations
Asset retirement obligations primarily consist of estimated costs to remove, dismantle and restore land or seabed at the end of oil and gas production operations. Changes in asset retirement obligations were as follows:
June 30,June 30,
(In millions)(In millions)20222021(In millions)20232022
Beginning balance as of January 1Beginning balance as of January 1$316 $254 Beginning balance as of January 1$340 $316 
Incurred liabilities, including acquisitionsIncurred liabilities, including acquisitionsIncurred liabilities, including acquisitions
Settled liabilities, including dispositionsSettled liabilities, including dispositions(3)(2)Settled liabilities, including dispositions(20)(3)
Accretion expense (included in depreciation, depletion and amortization)Accretion expense (included in depreciation, depletion and amortization)Accretion expense (included in depreciation, depletion and amortization)
Revisions of estimatesRevisions of estimates(5)32 Revisions of estimates(5)
Ending balance as of June 30, totalEnding balance as of June 30, total$323 $296 Ending balance as of June 30, total$339 $323 
Ending balance as of June 30, short-termEnding balance as of June 30, short-term$46 $24 Ending balance as of June 30, short-term$40 $46 
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2021In the second quarter of 2021, we had a revision of estimate of $29 million related
MARATHON OIL CORPORATION
Notes to anticipated costs for decommissioning certain wells, pipelines and production facilities for previously divested offshore non-producing long-lived assets located in the Gulf of Mexico. As of June 30, 2021, $14 million of this revision of estimate was classified as short-term. See Consolidated Financial Statements (Unaudited)
Note 22 for further information. During the quarter, we recognized $22 million of impairment expense associated with these non-producing long-lived assets within our consolidated statements of income. See Note 10 for further information.

12.11. Leases
Lessee
Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows:
(In millions)Balance Sheet Location:June 30, 2022December 31, 2021
ROU assets:
Operating leasesOther noncurrent assets$119 $59 
Finance leasesOther noncurrent assets26 28 
Total ROU assets$145 $87 
Lease liabilities:
Current liabilities
Operating leasesOther current liabilities$78 $40 
Finance leasesOther current liabilities
Noncurrent liabilities
Operating leasesDeferred credits and other liabilities45 23 
Finance leasesDeferred credits and other liabilities20 24 
Total lease liabilities$149 $93 
15

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
(In millions)Balance Sheet Location:June 30, 2023December 31, 2022
ROU assets:
Operating leasesOther noncurrent assets$118 $123 
Finance leasesOther noncurrent assets21 24 
Total ROU assets$139 $147 
Lease liabilities:
Current liabilities
Operating leasesOther current liabilities$83 $94 
Finance leasesOther current liabilities
Noncurrent liabilities
Operating leasesDeferred credits and other liabilities38 32 
Finance leasesDeferred credits and other liabilities15 18 
Total lease liabilities$142 $150 
Operating Leases
We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and the majority of our existing leases are classified as either short-term or long-term operating leases.
Finance Leases
In 2018, we signed an agreement with an owner/lessor to construct and lease a new build-to-suit office building in Houston, Texas. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In March 2022, we made our first cash lease payment. ForDuring the six months ended June 30, 2023 and 2022, ourwe have made cash lease payments weretotaling approximately $10 million and $2 million.million, respectively. At the end of the initial lease term, we can negotiate to extend the lease term for an additional five years, subject to the approval of the participants; purchase the property subject to certain terms and conditions; or remarket the property to an unrelated third party. The lease contains a residual value guarantee of 100% of the total acquisition and construction costs.
Lessor
Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in E.G., which is occupied by EGHoldings, a related party equity method investee see Note 2120. The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below.
(In millions)(In millions)Operating Lease Future Cash Receipts(In millions)Operating Lease Future Cash Receipts
2022$
202320232023$
202420242024
202520252025
202620262026
20272027
ThereafterThereafter48 Thereafter42 
Total undiscounted cash flowsTotal undiscounted cash flows$75 Total undiscounted cash flows$69 
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13.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


12.  Derivatives
We may use derivatives to manage a portion of our exposure to commodity price risk, commodity locational risk and interest rate risk. For further information regarding the fair value measurement of derivative instruments, see Note 1413. All of our commodity derivatives and interest rate derivatives are subject to enforceable master netting arrangements or similar agreements under which we report net amounts.
The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with where they appear on thetheir locations in our consolidated balance sheets.
June 30, 2022June 30, 2023
(In millions)(In millions)AssetLiabilityNet Asset (Liability)Balance Sheet Location(In millions)AssetLiabilityNet Asset (Liability)Balance Sheet Location
Not Designated as HedgesNot Designated as HedgesNot Designated as Hedges
CommodityCommodity$$$— Other current assetsCommodity$$— $Other current assets
Commodity83 (79)Other current liabilities
Total Not Designated as HedgesTotal Not Designated as Hedges$$85 $(79)Total Not Designated as Hedges$$— $
Cash Flow HedgesCash Flow HedgesCash Flow Hedges
Interest RateInterest Rate$$— $Other current assetsInterest Rate$10 $— $10 Other current assets
Interest RateInterest Rate12 — 12 Other noncurrent assetsInterest Rate14 — 14 Other noncurrent assets
Total Designated HedgesTotal Designated Hedges$16 $— $16 Total Designated Hedges$24 $— $24 
TotalTotal$22 $85 $(63)Total$33 $— $33 

16

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
December 31, 2021
(In millions)AssetLiabilityNet Asset (Liability)Balance Sheet Location
Not Designated as Hedges
Commodity(7)Other current liabilities
Interest Rate27 — 27 Other noncurrent assets
Total Not Designated as Hedges$28 $$20 
Cash Flow Hedges
Interest Rate$— $$(3)Other current liabilities
Interest Rate— (2)Deferred credits and other liabilities
Total Designated Hedges$— $$(5)
Total$28 $13 $15 

December 31, 2022
(In millions)AssetLiabilityNet Asset (Liability)Balance Sheet Location
Not Designated as Hedges
Commodity$10 $— $10 Other current assets
Total Not Designated as Hedges$10 $— $10 
Cash Flow Hedges
Interest Rate$$— $Other current assets
Interest Rate15 — 15 Other noncurrent assets
Total Designated Hedges$24 $— $24 
Total$34 $— $34 
Derivatives Not Designated as Hedges
Commodity Derivatives
We have entered into multiple crude oil and natural gas derivatives indexed to thetheir respective indices as noted in the table below, related to a portion of our forecasted U.S. sales through 2023. These derivatives consist ofare three-way collars, two-way collars and NYMEX roll basis swaps.collars. Three-way collars consist of a sold call (ceiling), a purchased put (floor) and a sold put. The ceiling price is the maximum we will receive for the contract volumes; the floor is the minimum price we will receive, unless the market price falls below the sold put strike price. In this case, we receive the NYMEX WTI price or the Henry Hub price plus the difference between the floor and the sold put price. These crude oil and natural gas derivatives were not designated as hedges.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


The following table sets forth outstanding derivative contracts as of June 30, 2022,2023, and the weighted average prices for those contracts:
20222023
Third QuarterFourth QuarterFirst Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)30,000 30,000 0
Weighted average price per Bbl:
Ceiling$97.52 $97.52 0
Floor$56.67 $56.67 0
Sold put$46.67 $46.67 0
NYMEX Roll Basis Swaps
Volume (Bbls/day)60,000 60,000 0
Weighted average price per Bbl$0.67 $0.67 0
Natural Gas
Henry Hub (“HH”) Two-Way Collars
Volume (MMBtu/day)50,000 50,000 
Weighted average price per MMBtu:
Ceiling$19.28 $19.28 
Floor$5.00 $5.00 
Henry Hub Three-Way Collars
Volume (MMBtu/day)100,000 100,000 0
Weighted average price per MMBtu:
Ceiling$7.13 $7.13 0
Floor$3.88 $3.88 0
Sold Put$2.88 $2.88 0

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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
2023
Third QuarterFourth Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)10,000 10,000 
Weighted average price per Bbl:
Ceiling$97.59 $97.59 
Floor$60.00 $60.00 
Sold put$45.00 $45.00 
Natural Gas
Henry Hub Three-Way Collars
Volume (MMBtu/day)50,000 50,000 
Weighted average price per MMBtu:
Ceiling$11.14 $11.14 
Floor$4.00 $4.00 
Sold Put$2.50 $2.50 
The unrealized and realized gain (loss) impact of our commodity derivative instruments appears in the table below and is reflected in net gain (loss) on commodity derivatives in the consolidated statements of income.
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
(In millions)(In millions)2022202120222021(In millions)2023202220232022
Unrealized gain (loss) on derivative instruments, netUnrealized gain (loss) on derivative instruments, net$43 $(75)$(71)$(157)Unrealized gain (loss) on derivative instruments, net$(4)$43 $(2)$(71)
Realized gain (loss) on derivative instruments, net(a)
Realized gain (loss) on derivative instruments, net(a)
$(70)$(91)$(99)$(162)
Realized gain (loss) on derivative instruments, net(a)
$$(70)$20 $(99)
(a)During the second quarter and first six months of 2023, net cash received for settled derivative positions was $7 million and $17 million, respectively. During the second quarter and first six months of 2022, net cash paid for settled derivative positions was $61 million and $89 million, respectively. During the second quarter and first six months of 2021, net cash paid for settled derivative positions was $84 million and $95 million, respectively.
Interest Rate Swaps
During 2020, we entered into forward starting interest rate swaps with a notional amount of $350 million to hedge variations in cash flows arising from fluctuations in the LIBOR benchmark interest rate related to forecasted interest payments of a future debt issuance in 2025. The expected proceeds of the future debt issuance were intended to refinance theour $900 million 3.85% Senior Notes due 2025 (“2025 Notes”). In September 2021, we fully redeemed these 2025 Notes. In March 2022, we closed these positions and settled the interest rate swaps for proceeds of $44 million. During the six months ended June 30, 2022, we recorded a cumulative $17 million gain within net interest forand other within our consolidated statements of income related to these swaps.
During the second quarter of 2021, we de-designated $25 million of the $320 million Houston office cash flow hedges (discussed further in the Derivatives Designated as Cash Flow Hedges section below), as the construction cost budget estimate was reduced. These interest rate swap contracts began to settle in January 2022. On June 10, 2022, we closed the $25 million de-designated hedges, which resulted in cash proceeds of approximately $2 million. As of June 30, 2022, the remaining open interest rate swaps for the Houston office (with a notional amount of $295 million) are still classified as cash flow hedges.
The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements. These positions were fully liquidated as of June 30, 2022.
June 30, 2022December 31, 2021
Maturity Date
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
June 1, 2025$— — %$350 0.95 %
September 9, 2026$— — %$25 1.45 %
Derivatives Designated as Cash Flow Hedges
During 2019, we entered into forward starting interest rate swaps with a total notional amountmaturity date of $320 millionSeptember 9, 2026 to hedge variations in cash flows related to the 1-month LIBORinterest rate component of future lease payments of our future Houston office. DuringAs of June 30, 2023 and December 31, 2022, the second quarter of 2021, we de-designated $25 million of these hedges as the construction cost budget estimate associated with the project was reduced (see discussion in preceding section). The notional amount of open interest rate swaps for the Houston office iswas $295 million. The weighted average secured overnight financing rate (“SOFR”) for the swaps was 1.43% as of both June 30, 2023 and December 31, 2022.
The Houston office lease commenced in September 2021, however, our first cash lease payment for February 2022 rent was paid in March.March 2022. The first settlement date for the interest rate swaps was in January 2022. The last swap will mature in September 2026. During the second quarter and first six months of2022,ended June 30, 2023, net cash paidreceived for the settled interest rate swap positions was $1 million and $2 million, respectively.$5 million. As of June 30, 2022,2023, we expect to reclassify $5a $11 million gain from accumulated other comprehensive income into theour consolidated statements of income statement over the next twelve months. See Note 1211 for further details regarding the lease of the Houston office.
The following table presents, by maturity date, information about our interest rate swap agreements, including the fixed weighted average LIBOR.
June 30, 2022December 31, 2021
Maturity Date
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
September 9, 2026$295 1.52 %$295 1.52 %

office lease.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)

14.
13.    Fair Value Measurements
Fair Values – Recurring
The following tables present assets and liabilities accounted for at fair value on a recurring basis as of June 30, 20222023 and December 31, 20212022 by hierarchy level.
June 30, 2022June 30, 2023
(In millions)(In millions)Level 1Level 2Level 3Total(In millions)Level 1Level 2Level 3Total
Derivative instruments, assetsDerivative instruments, assetsDerivative instruments, assets
Commodity(a)
Commodity(a)
$— $$— $
Interest rate - designated as cash flow hedgesInterest rate - designated as cash flow hedges— 16 — 16 Interest rate - designated as cash flow hedges— 24 — 24 
Derivative instruments, assetsDerivative instruments, assets$— $16 $— $16 Derivative instruments, assets$— $33 $— $33 
Derivative instruments, liabilities
Commodity(a)
$(23)$(56)$— $(79)
Derivative instruments, liabilities$(23)$(56)$— $(79)
Total$(23)$(40)$— $(63)
December 31, 2021 December 31, 2022
(In millions)(In millions)Level 1Level 2Level 3Total(In millions)Level 1Level 2Level 3Total
Derivative instruments, assetsDerivative instruments, assetsDerivative instruments, assets
Interest rate - not designated as cash flow hedges$— $27 $— $27 
Derivative instruments, assets$— $27 $— $27 
Derivative instruments, liabilities
Commodity(a)
Commodity(a)
$(2)$(5)$— $(7)
Commodity(a)
$— $10 $— $10 
Interest rate - designated as cash flow hedgesInterest rate - designated as cash flow hedges— (5)— (5)Interest rate - designated as cash flow hedges— 24 — 24 
Derivative instruments, liabilities$(2)$(10)$— $(12)
Total$(2)$17 $— $15 
Derivative instruments, assetsDerivative instruments, assets$— $34 $— $34 
(a)Commodity derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 1312.
CommodityAs of June 30, 2023, our commodity derivatives include three-way collars, two-way collars and NYMEX roll basis swaps.collars. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. For commodity swaps, inputs to the models include only commodity prices and interest rates and are categorized as Level 1 because all assumptions and inputs are observable in active markets throughout the term of the instruments. For three-way collars, inputs to the models include commodity prices and implied volatility and are categorized as Level 2 because predominantly all assumptions and inputs are observable in active markets throughout the term of the instruments.
The forward starting interest rate swaps are measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 1312 for detaildetails on the forward starting interest rate swaps.
Fair Values – Nonrecurring
See Note 10for detail on our fair values related to impairments.
Fair Values – Financial Instruments
Our current assets and liabilities include financial instruments, the most significant of which are receivables, the current portion of our long-term debt and payables. We believe the carrying values of our receivables and payables approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our credit rating and (3) our historical incurrence of and expected future insignificant bad debt expense, which includes an evaluation of counterparty credit risk.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
The following table summarizes financial instruments, excluding receivables, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at June 30, 20222023 and December 31, 2021.2022.
June 30, 2022December 31, 2021June 30, 2023December 31, 2022
(In millions)(In millions)Fair ValueCarrying AmountFair ValueCarrying Amount(In millions)Fair ValueCarrying AmountFair ValueCarrying Amount
Financial assetsFinancial assets    Financial assets    
Current assets$— $— $11 $10 
Other noncurrent assetsOther noncurrent assets10 28 12 27 Other noncurrent assets$10 $28 $10 $28 
Total financial assetsTotal financial assets$10 $28 $23 $37 Total financial assets$10 $28 $10 $28 
Financial liabilitiesFinancial liabilities    Financial liabilities    
Current liabilities$110 $166 $99 $136 
Other current liabilitiesOther current liabilities$130 $195 $140 $204 
Long-term debt, including current portion(a)
Long-term debt, including current portion(a)
3,996 4,000 4,705 4,033 
Long-term debt, including current portion(a)
5,742 5,878 5,806 5,948 
Deferred credits and other liabilitiesDeferred credits and other liabilities16 15 46 46 Deferred credits and other liabilities62 63 73 73 
Total financial liabilitiesTotal financial liabilities$4,122 $4,181 $4,850 $4,215 Total financial liabilities$5,934 $6,136 $6,019 $6,225 
(a)Excludes debt issuance costs.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


Fair values of our financial assets included in other noncurrent assets, and of our financial liabilities included in other current liabilities and deferred credits and other liabilities, are measured using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value.
All of our long-termOur fixed rate debt instruments are publicly traded. AThe fair value of our fixed rate debt is measured using a market approach, based upon quotes from major financial institutions, which are Level 2 inputs,inputs. Our floating rate debt is used to measure thenon-public and consists of borrowings under our Term Loan Facility and Revolving Credit Facility. The fair value of our debt.floating rate debt approximates the carrying value and is estimated based on observable market-based inputs, which results in a Level 2 classification.
15.14.    Debt
Term Loan Facility
In November 2022, we entered into a term credit agreement, which provides for a two-year $1.5 billion term loan facility (“Term Loan Facility”) and we borrowed the full amount thereunder in December 2022. Borrowings under the Term Loan Facility can be prepaid without penalty. As of June 30, 2023, we had $1.5 billion in borrowings under our Term Loan Facility. The second quarter weighted average interest rate on borrowings under the Term Loan Facility was 6.84%.
The Term Loan Facility includes a covenant requiring our total debt to total capitalization ratio not to exceed 65% as of the last day of each fiscal quarter. In the event of a default, the lenders holding more than half of the commitments may terminate all of the commitments under the Term Loan Facility and require the immediate repayment of all outstanding borrowings under the Term Loan Facility. As of June 30, 2023, we were in compliance with this covenant with a ratio of 26%.
Revolving Credit Facility
As of June 30, 2022,2023, we had no borrowings of $450 million against our $3.1$2.5 billion unsecured revolving credit facility (“Credit Facility”).

On July 28, 2022, we executed the seventh amendment to ourRevolving Credit Facility. The primary changes tosecond quarter weighted average interest rate on borrowings under the Revolving Credit Facility effected by this amendment were to (i) extend the maturity date of the Credit Facility by three years to July 28, 2027, (ii) decrease the size of the Credit Facility from $3.1 billion to $2.5 billion, (iii) replace the LIBOR interest rate benchmark with the secured overnight financing rate (“SOFR”) and (iv) implement certain revisions to the Pricing Schedule.was 6.96%.
The Revolving Credit Facility includes a covenant requiring our total debt to total capitalization ratio not to exceed 65% as of the last day of each fiscal quarter. In the event of a default, the lenders holding more than half of the commitments may terminate the commitments under the Revolving Credit Facility and require the immediate repayment of all outstanding borrowings and the cash collateralization of all outstanding letters of credit under the Revolving Credit Facility. As of June 30, 2022,2023, we were in compliance with this covenant with a ratio of 19%26%.
Commercial Paper Program
During the second quarter of 2023, we obtained ratings for our commercial paper from Moody’s, Standard & Poor’s and Fitch. Pursuant to our U.S. commercial paper program, we may issue unsecured notes in a maximum aggregate face amount of $2.5 billion outstanding at any time, with maturities up to 365 days from the date of issuance. Our $2.5 billion U.S. commercial paper program is backed by our $2.5 billion Revolving Credit Facility and can be used to fund short-term working capital requirements. We did not issue commercial paper during the second quarter of 2023.
Debt Redemption
In May 2022,March 2023, we redeemedrepaid the $32$70 million 9.375%8.5% Senior Notes on the maturity date.
Long-term debt
At June 30, 2022,2023, we had $4.0$5.9 billion of total long-term debt outstanding, which includes $273 million of long-term debt due within one year. Included in long-termoutstanding. Long-term debt due within one year is $200consists of $131 million of 8.125% Senior Notes, which were repaid in 2.0% Bonds which feature a mandatory purchaseconnection with their maturity on April 1,July 17, 2023. We currently intend to retire our outstanding long-term debt as it matures. Refer to our 20212022 Annual Report on Form 10-K for a listing of our long-term debt maturities.
Debt Remarketing
On April 3, 2023, we closed a $200 million remarketing to investors of sub-series 2017A-1 bonds that are part of the $1 billion St. John the Baptist Parish, State of Louisiana revenue refunding bonds Series 2017. The bonds are subject to an interest rate of 4.05% and a mandatory purchase date of July 1, 2026. The repayment and new borrowing associated with the remarketed bonds are presented separately within Debt repayments and Borrowings, respectively, within the Consolidated Statements of Cash Flows.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)

16.
15.    Stockholders’ Equity
Our Board of Directors has authorized a share repurchase program. During the first six months of 2022,2023, we repurchased approximately $1.4 billion of29 million shares of our common stock pursuant to the share repurchase program. On May 4, 2022, our Boardprogram at a cost of Directors increased our remaining share repurchase program to $2.5 billion. The total$706 million. Our remaining share repurchase authorization was approximately $2.0$1.8 billion at June 30, 2022.2023. Purchases under the program are made at our discretion and may be in either open market transactions, including block purchases, or in privately negotiated transactions using cash on hand, cash generated from operations or proceeds from potential asset sales. This program may be changed based upon our financial condition or changes in market conditions and is subject to termination prior to completion.
Additionally, during the first six months of 20222023 we repurchased $21$30 million of shares related to our tax withholding obligation associated with the vesting of employee restricted stock awards and restricted stock units; these repurchases do not impact our share repurchase program authorization.
Subsequent to the quarter, we repurchased approximately $282 million of shares of our common stock through August 3, 2022.
17.16.    Incentive Based Compensation
Stock options, restricted stock and restricted stock units
The following table presents a summary of activity for the first six months of 2022:2023: 
Stock OptionsRestricted Stock & Units Stock OptionsRestricted Stock & Units
Number of SharesWeighted Average Exercise PriceNumber of Shares & UnitsWeighted Average Grant Date Fair ValueNumber of SharesWeighted Average Exercise PriceNumber of Shares & UnitsWeighted Average Grant Date Fair Value
Outstanding at December 31, 20214,274,304  $22.13 5,888,242 $10.98 
Outstanding at December 31, 2022Outstanding at December 31, 20221,678,524 $28.86 4,651,196 $14.89 
GrantedGranted— 

$— 1,428,041 $22.89 Granted— 

$— 1,832,506 $25.79 
Exercised/VestedExercised/Vested(1,842,093)$14.41 (2,738,788)$12.01 Exercised/Vested(10,417)$10.47 (2,597,783)$11.99 
CanceledCanceled(167,906)$34.55 (104,351)$13.49 Canceled(122,054)$33.68 (116,259)$20.19 
Outstanding at June 30, 20222,264,305  $27.48 4,473,144 $14.09 
Outstanding at June 30, 2023Outstanding at June 30, 20231,546,053 $28.61 3,769,660 $22.02 
Stock-based performance unit awards
During the first six months of 2022,2023, we granted 167,043222,464 stock-based performance units to eligible officers, which are settled in shares. The grant date fair value per unit was $34.07.$32.97. During the first six months of 2022,2023, we stock settled the units related to the 2020 grant. At June 30, 2023, there were 686,266 outstanding stock-based performance units to be settled in shares to officers.
During the first six months of 2023, we also granted 167,043222,464 stock-based performance units to eligible officers, which are settled in cash. At the grant date for these performance units, each unit represents the value of 1one share of our common stock. The fair value of each cash-settled performance unit was $22.63$23.22 as of June 30, 2022.2023. During the first six months of 2023, we also cash settled the units related to the 2021 grant. At June 30, 2023, there were 389,507 units outstanding of the stock-based performance unit awards to be settled in cash to officers.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)

18.
17.    Defined Benefit Postretirement Plans
The following table summarizes the components of net periodic benefit costs (credits):
Three Months Ended June 30,Three Months Ended June 30,
Pension BenefitsOther BenefitsPension BenefitsOther Benefits
(In millions)(In millions)2022202120222021(In millions)2023202220232022
Service costService cost$$$— $— Service cost$$$— $— 
Interest costInterest costInterest cost— 
Expected return on plan assetsExpected return on plan assets(3)(2)— — Expected return on plan assets(2)(3)— — 
Amortization:Amortization:Amortization:
– prior service credit– prior service credit(1)(1)(4)(4)– prior service credit(1)(1)(4)(4)
– actuarial loss– actuarial loss— — – actuarial loss— — 
Net settlement loss(a)
Net settlement loss(a)
— — — 
Net settlement loss(a)
— — — — 
Net periodic benefit costs (credits)(b)
Net periodic benefit costs (credits)(b)
$$$(3)$(3)
Net periodic benefit costs (credits)(b)
$$$(3)$(3)

Six Months Ended June 30,Six Months Ended June 30,
Pension BenefitsOther BenefitsPension BenefitsOther Benefits
(In millions)(In millions)2022202120222021(In millions)2023202220232022
Service costService cost$$$— $— Service cost$$$— $— 
Interest costInterest costInterest cost
Expected return on plan assetsExpected return on plan assets(5)(4)— — Expected return on plan assets(4)(5)— — 
Amortization:Amortization:Amortization:
– prior service credit– prior service credit(3)(3)(8)(8)– prior service credit(3)(3)(8)(8)
– actuarial loss– actuarial loss– actuarial loss— 
Net settlement loss(a)
Net settlement loss(a)
— — — 
Net settlement loss(a)
— — — 
Net periodic benefit costs (credits)(b)
Net periodic benefit costs (credits)(b)
$$13 $(6)$(6)
Net periodic benefit costs (credits)(b)
$$$(6)$(6)
(a)Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan’s total service and interest cost for that year.
(b)Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets which recognizes changes in fair value over three years.

During the first six months of 2022,2023, we made contributions of $9$6 million to our funded pension plan.plan and we expect to make additional contributions of $6 million this year. We also made a paymentpayments of $5$3 million related to each of our unfunded pension plan and other postretirement benefit plans. We expect to contribute an additional $8 million in contributions to our funded pension plan this year.
22

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
19.��18.    Reclassifications Out of Accumulated Other Comprehensive Income (Loss)
The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss):
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
(In millions)(In millions)2022202120222021Income Statement Line(In millions)2023202220232022Income Statement Line
Postretirement and postemployment plansPostretirement and postemployment plansPostretirement and postemployment plans
Amortization of prior service creditAmortization of prior service credit$$$11 $11 Other net periodic benefit costsAmortization of prior service credit$$$11 $11 Other net periodic benefit credits
Amortization of actuarial lossAmortization of actuarial loss(1)(1)(2)(4)Other net periodic benefit costsAmortization of actuarial loss(1)(1)(1)(2)Other net periodic benefit credits
Net settlement lossNet settlement loss— (5)— (5)Other net periodic benefit costsNet settlement loss— — (1)— Other net periodic benefit credits
Interest rate swaps
Reclassification of de-designated forward interest rate swaps— (30)— (28)Net interest and other
(1)— (2)— Provision (benefit) for income taxes
Total reclassifications of (income) expense, net of tax (a)
$$(31)$$(26)Net income (loss)
Income TaxIncome Tax(1)(1)(2)(2)Provision (benefit) for income taxes
Total reclassifications of expense, net of taxTotal reclassifications of expense, net of tax$$$$Net income
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)


19.    Supplemental Cash Flow Information
 Six Months Ended June 30,
(In millions)20232022
Included in operating activities:  
Interest paid(a)
$139 $99 
Income taxes paid, net of refunds$97 $93 
Noncash investing activities:  
Increase in asset retirement costs$12 $
(a)During 2021 we had a full valuation allowance on net federal deferred tax assets inThe increase during the U.S. and as such, there is no tax impact to our postretirement and postemployment plans for the three and six months ended June 30, 2021.2023 compared to the same period in 2022 was primarily related to interest paid on borrowings under the Term Loan Facility and Revolving Credit Facility.
20.    Supplemental Cash Flow Information
 Six Months Ended June 30,
(In millions)20222021
Included in operating activities:  
Interest paid$99 $123 
Income taxes paid to (received from) taxing authorities, net of refunds$93 $
Noncash investing activities:  
Increase in asset retirement costs$$38 

Other noncash investing activities include accrued capital expenditures for the six months ended June 30, 2023 and 2022 of $169 million and 2021 of $116 million, and $85 million, respectively.
23

MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)
21.20.    Equity Method Investments
During the periods ended June 30, 20222023 and December 31, 20212022 our equity method investees were considered related parties. Our investment in our equity method investees are summarized in the following table:
(In millions)Ownership as of June 30, 2022June 30, 2022December 31, 2021
EGHoldings (a)
56%$226 $148 
Alba Plant LLC (b)
52%166 154 
AMPCO (c)
45%136 148 
Total $528 $450 
(In millions)Ownership as of June 30, 2023June 30, 2023December 31, 2022
EGHoldings (a)
56%$118 $287 
Alba Plant LLC (b)
52%163 155 
AMPCO (c)
45%149 135 
Total $430 $577 
(a)EGHoldings is engaged in LNG production activity.
(b)Alba Plant LLC processes LPG.
(c)AMPCO is engaged in methanol production activity.
Summarized, 100% combined financial information for equity method investees is as follows:
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2022202120222021
Income data:
Revenues and other income$459 $246 $833 $481 
Income (loss) from operations306 111 535 207 
Net income (loss)$272 $85 $476 $157 

Three Months Ended June 30,Six Months Ended June 30,
(In millions)2023202220232022
Income data:
Revenues and other income$183 $459 $489 $833 
Income from operations43 306 202 535 
Net income$30 $272 $164 $476 
Revenues from related parties were $5 million and $11 million for the three and six months ended June 30, 2023 and $7 million and $15 million for the three and six months ended June 30, 2022, respectively, $8 million and $16 million for the three and six months ended June 30, 2021, respectively, with the majority related to EGHoldings in allboth periods.
Cash received from equity investees is classified as dividends or return of capital on the Consolidated Statements of Cash Flows. Dividends from equity method investees are reflected in the Operating activities section in Equity Method Investments, net while return of capital is reflected in the Investing activities section. Dividends and return of capital received by us totaled $249 million during the three and six months ended June 30, 2023 and $146 million and $200 million forduring the three and six months ended June 30, 2022, respectively, and $50 million and $81 million for the three and six months ended June 30, 2021, respectively.
Current receivables from related parties at June 30, 20222023 and December 31, 20212022 were $28$15 million and $23$36 million, respectively, with the majoritywhich primarily related to EGHoldings in both periods. Payables to related parties at June 30, 2023 and December 31, 2022 were $6$14 million with the majority related to EGHoldings and $20 million, at December 31, 2021,respectively, with the majority related to Alba Plant LLC.
22.    Commitments and Contingencies
In the second quarter of 2019, Marathon E.G. Production Limited (“MEGPL”), a consolidated and wholly owned subsidiary, signed a series of agreements to process third-party Alen Unit gas through existing infrastructure locatedLLC in Punta Europa, E.G. Our equity method investee, Alba Plant LLC, is also a party to some of the agreements. These agreements require (subject to certain limitations) MEGPL to indemnify the owners of the Alen Unit against injury to Alba Plant LLC’s personnel and damage to or loss of Alba Plant LLC’s automobiles, as well as third party claims caused by Alba Plant LLC and certain environmental liabilities arising from certain hydrocarbons in the custody of Alba Plant LLC. At this time, we cannot reasonably estimate this obligation as we do not have any history of prior indemnification claims or environmental discharge or contamination. Therefore, we have not recorded a liability with respect to these indemnities since the amount of potential future payments under these indemnification clauses is not determinable.
The agreements to process the third-party Alen Unit gas required the execution of third-party guarantees by Marathon Oil Corporation in favor of the Alen Unit’s owners. NaN separate guarantees were executed during the second quarter of 2020; one for a maximum of approximately $91 million pertaining to the payment obligations of Equatorial Guinea LNG Operations, S.A. and another for a maximum of $25 million pertaining to the payment obligations of Alba Plant LLC. Payment by us would be required if any of those entities fails to honor its payment obligations pursuant to the relevant agreements with the owners of the Alen Unit. Certain owners of the Alen Unit, or their affiliates, are also direct or indirect shareholders in Equatorial Guinea LNG Operations, S.A. and Alba Plant LLC. Each guarantee expires no later than December 31, 2027. We measured these guaranteesboth periods.
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MARATHON OIL CORPORATION
Notes to Consolidated Financial Statements (Unaudited)

at fair value using the net present value of premium payments we expect to receive from our investees. Our liability for these guarantees was approximately $4 million as of June 30, 2022. Each of Equatorial Guinea LNG Operations, S.A.
21.    Commitments and Equatorial Guinea LNG Train 1, S.A. provided us with a pledge of its receivables as recourse against any payments we may make under the guaranty of Equatorial Guinea LNG Operations, S.A.’s performance.Contingencies
Various groups, including the State of North Dakota and 3three Indian tribes (the “NaN“Three Affiliated Tribes”) represented by the Bureau of Indian Affairs, have been involved in a dispute regarding the ownership of certain lands underlying the Missouri River and Little Missouri River (the “Disputed Land”) from which we currently produce. As a result, as of June 30, 2022,2023, we have a $145$165 million current liability in suspended royalty and working interest revenue, including interest, of which $133$144 million was included within accounts payable and $12$21 million related to accrued interest and was included within other current liabilities on our consolidated balance sheet. Additionally, we have a long-term receivable of $25$26 million for capital and expenses. The United States Department of the Interior (“DOI”) has addressed the United States’ position with respect to this dispute several times over the past fivein recent years with conflicting opinions. In January 2017, the DOI issued an opinion that the Disputed Land is held in trust for the NaNThree Affiliated Tribes, then in June 2018 and May 2020 the DOI issued opinions concluding that the State of North Dakota held title to the Disputed Land. Most recently, on February 4, 2022, the DOI issued an opinion (“M-Opinion”) concluding the DOI’s position that the Disputed Land is held in trust for the NaNThree Affiliated Tribes. While the latest M-Opinion is binding on all agencies within the DOI, it is not legally binding on third parties, including Marathon Oil, or a court. Depending on the ultimate outcome of this title dispute, the NaNThree Affiliated Tribes could challenge the validity of certain of our leases relating to a portion of the disputed land, and if such challenge were successful it could result in operational delays and additional costs to us. Given the uncertainty in matters such as these, we are unable to predict the ultimate outcome of this matter at this time; however, we believe the resolution of this matter will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.
We are a defendant in a number of legal and administrative proceedings arising in the ordinary course of business including, but not limited to, royalty claims, contract claims, tax disputes and environmental claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. In addition, we may also be subject to retained liabilities with respect to certain divested assets by operation of law. For example, we are exposed to the risk that owners and/or operators of assets purchased from us become unable to satisfy plugging or abandonment obligations that attach to those assets. In that event, due to operation of law, we may be required to assume plugging or abandonment obligations for those assets. Although we have established reserves for such liabilities, we could be required to accrue additional amounts in the future and these amounts could be material.
Marathon Oil has been named in various lawsuits alleging royalty underpayments in our domestic operations. We intend to vigorously defend ourselves against such claims. For instance, Marathon Oil has beenwas named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and after plaintiffs have soughtlost their attempt to certify a class certification, whichaction, a settlement was reached, and in the first quarter of 2023 such settlement was approved by the court has so far denied. and paid.
We have accrued for potential liabilities associated with these lawsuits based on currently available information; however, actual losses may exceed our accruals or we could be required to accrue additional amounts in the future.
In January 2020, we received a Notice of ViolationViolations (“NOV”)’s from the EPA related to allegations of violations of the Clean Air Act.Act with respect to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. We arecontinue to actively negotiatingnegotiate a draft consent decree with the EPA and Department of Justice containing certain proposed injunctive terms relating to this enforcement action. The resolution of the enforcement action will likely include monetary sanctions and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. GivenWe maintain an accrual for estimated future costs related to this matter regarding actions required to retrofit or replace existing equipment, which we expect to incur over multiple years. Our accrual does not include possible monetary sanctions or costs associated with mitigation projects as we are currently unable to estimate those amounts. Through the date of this filing, there exists substantial uncertainty as to the ultimate result of this matter and it is reasonably possible the result could be materially different from our expectations and our accrual.
The Company received NOV’s from the EPA relating to alleged Clean Air Act violations following flyovers conducted in matters such as2020 and 2022 over certain of the Company’s oil and gas facilities in New Mexico. The notices involve alleged emission and permitting violations. We initiated discussions with the EPA to resolve these matters. As we are still investigating these allegations, we are unable to predictestimate the ultimate outcomepotential loss associated with these matters, however, it is reasonably possible that resolution of this matter at this time. However, we believe that any penalties, mitigation costs or corrective actions thatthese matters may result from this matter will not havein a material adverse effect on our consolidated financial position, resultsfine or penalty in excess of operations or cash flows.$300,000.
We have incurred and will continue to incur capital, operating and maintenance and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately offset by the prices we receive for our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas and production processes. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites. Penalties may be imposed for noncompliance.
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Notes to Consolidated Financial Statements (Unaudited)


At June 30, 2022,2023, accrued liabilities for remediation relating to environmental laws and regulations were not material. It is not presently possible to estimate the ultimate amount of all remediation cost that might be incurred or the penalties that may be imposed.
In the second quarter of 2019, Marathon E.G. Production Limited (“MEGPL”), a consolidated and wholly owned subsidiary, signed a series of agreements to process third-party Alen Unit gas through existing infrastructure located in Punta Europa, E.G. Our equity method investee, Alba Plant LLC, is also a party to some of the agreements. These agreements require (subject to certain limitations) MEGPL to indemnify the owners of the Alen Unit against injury to Alba Plant LLC’s personnel and damage to or loss of Alba Plant LLC’s automobiles, as well as third party claims caused by Alba Plant LLC and certain environmental liabilities arising from certain hydrocarbons in the custody of Alba Plant LLC. At this time, we cannot reasonably estimate this obligation as we do not have any history of prior indemnification claims or environmental discharge or contamination. Therefore, we have not recorded a liability with respect to these indemnities since the amount of potential future payments under these indemnification clauses is not determinable.
The agreements to process the third-party Alen Unit gas required the execution of third-party guarantees by Marathon Oil Corporation in favor of the Alen Unit’s owners. Two separate guarantees were executed during the second quarter of 2020; one for a maximum of approximately $91 million pertaining to the payment obligations of Equatorial Guinea LNG Operations, S.A. and another for a maximum of $25 million pertaining to the payment obligations of Alba Plant LLC. Payment by us would be required if any of those entities fails to honor its payment obligations pursuant to the relevant agreements with the owners of the Alen Unit. Certain owners of the Alen Unit, or their affiliates, are also direct or indirect shareholders in Equatorial Guinea LNG Operations, S.A. and Alba Plant LLC. Each guarantee expires no later than December 31, 2027. We measured these guarantees at fair value using the net present value of premium payments we expect to receive from our investees. Our liability for these guarantees was approximately $4 million as of June 30, 2023. Each of Equatorial Guinea LNG Operations, S.A. and Equatorial Guinea LNG Train 1, S.A. provided us with a pledge of its receivables as recourse against any payments we may make under the guaranty of Equatorial Guinea LNG Operations, S.A.’s performance.
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations 
Executive Overview
Outlook
Operations
Market Conditions
Results of Operations
Critical Accounting Estimates
Accounting Standards Not Yet Adopted
Cash Flows
Liquidity and Capital Resources
Environmental Matters and Other Contingencies
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the preceding consolidated financial statements and notes in Item 1.
Executive Overview
We are an independent exploration and production company, focused on U.S. resource plays: Eagle Ford in Texas, Bakken in North Dakota, STACK and SCOOP in Oklahoma and Northern DelawarePermian in New Mexico.Mexico and Texas. Our U.S. assets are complemented by our international operations in E.G. Our overall business strategy is to responsibly deliver competitive corporate return levels, free cash flow and cash returns to shareholders, all of which are sustainable and resilient through long-term commodity price cycles. We expect to achieve our business strategy by adherence to a disciplined reinvestment rate capital allocation framework that limits our capital expenditures relative to our expected cash flow from operations. Keeping our workforce safe, maintaining a strong balance sheet, responsibly meeting global energy demand with a focus on continuously improving environmental performance, serving as a trusted partner in our local communities and maintaining best in-class corporate governance standards are foundational to the execution of our strategy.
In December 2022, we closed on a transaction to acquire approximately 130,000 net proved and unproved acres, with an average 97% working interest, in the Eagle Ford resource play from Ensign Natural Resources (“Ensign”) for cash consideration of $3.0 billion.
Compared to the prior year’s quarter,same period of 2022, we experienced a significant increasedecrease in revenues,revenue and net income from operations and operating cash flow, allprimarily as a result of which were driven by higherlower commodity prices. Total company net sales volumes were roughly flat. Our cash generated from operations more than funded our capital program, dividend payments and share repurchases. These results and activities are consistent with our prioritizationincreased during the second quarter of free cash flow generation and adherence2023 when compared to our disciplined capital allocation framework.prior year quarter. Below are certain key financial and operational highlights for the quarter:
Improved financialFinancial and operational results
Our net income was $966$287 million in the second quarter of 20222023 as compared to net income of $16$966 million in the same period last year. Included in our financial results for the current quarter:
Revenues from contracts with customers increased $914decreased $684 million compared to the same quarter last year as a result of lower realized commodity prices, were significantly higher.partially offset by increased sales.
We recorded a net gain of $3 million on commodity derivatives as compared to a net loss of $27 million during the same quarter last year.
Income from equity method investments of $152decreased $130 million an increase of $103 million fromcompared to the same period in 2021, due to higherquarter last year as a result of lower realized commodity prices.
Net losses on commodity derivatives were lower by $139Depreciation, depletion and amortization was $559 million, which was an increase of $123 million as compared to the same quarter last year.
As a result of higher income before taxes, our provision for income taxesNet sales volumes in the U.S. segment increased by $269 million26% compared to the same quarterperiod last year. See Note 6 toyear, primarily driven by increased production from the consolidated financial statements for discussion of the increase in income taxes.acreage acquired from Ensign.




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Maintained investment grade balance sheet, increasedPrioritized return of capital to investors and maintained investment grade balance sheet
In the first six months of 2023, we repurchased $706 million of shares through our share repurchase program.
As of June 30, 2023, we have $215 million of cash on hand and $2.3 billion of total liquidity.
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Paid $125 million of dividends, or $0.20 per share, during the first six months of 2023, compared to dividends paid of $0.15 per share during the first six months of 2022.
All three primary credit rating agencies continue to rate us as investment grade.
As ofgrade, with Fitch and Moody’s reaffirming our credit rating in June 30, 2022, we have $1.2 billion of cash on hand and $4.3 billion of total liquidity. Refer to Liquidity and
Capital Resources for information on a subsequent event regarding the amendment of our Credit Facility.
In the first six months of 2022, we repurchased approximately $1.4 billion of shares through our share repurchase program.
Paid $108 million of dividends, or $0.15 per share, during the first six months of 2022. This is more than double the dividends paid of $0.07 per share during the first six months of 2021.2023.
Outlook
Capital Budget
Our Board of Directors has approvedIn February 2023, we announced a 20222023 capital budget of $1.3 billion. We continue$1.9 billion to monitor inflationary pressures given$2.0 billion that prioritizes free cash flow generation over production growth, consistent with our disciplined capital allocation framework. Approximately 60% of the labor market, commodity prices, supply chain challenges and geopolitical instability.2023 capital budget is weighted to the first half of the year.
Operations
The following table presents a summary of our sales volumes for each of our segments. Refer to Results of Operations for a price-volume analysis for each of the segments.
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
Net Sales VolumesNet Sales Volumes20222021Increase (Decrease)20222021Increase (Decrease)Net Sales Volumes20232022Increase (Decrease)20232022Increase (Decrease)
United States (mboed)
United States (mboed)
283 283— %282 279%
United States (mboed)
356 28326 %349 28224 %
International (mboed)
International (mboed)
60 65(8)%60 66(9)%
International (mboed)
44 60(27)%50 60(17)%
Total (mboed)
Total (mboed)
343 348(1)%342 345(1)%
Total (mboed)
400 34317 %399 34217 %
United States
Net sales volumes in the segment were consistent in the second quarter of 2022 as compared to the second quarter of 2021.
The following tables provide additional details regarding net sales volumes, sales mix and operational drilling activity for our significant operations within this segment:segment. Effective in 2023, the Texas Delaware oil play, which was previously included within Other United States as an exploration property, was integrated into the Permian resource play. The increase in net sales volumes in our U.S. segment compared to the same period in the prior year was primarily a result of our acquisition of the Eagle Ford assets of Ensign in December 2022.
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
Net Sales VolumesNet Sales Volumes20222021Increase (Decrease)20222021Increase (Decrease)Net Sales Volumes20232022Increase (Decrease)20232022Increase (Decrease)
Equivalent Barrels (mboed)
Equivalent Barrels (mboed)
Equivalent Barrels (mboed)
Eagle FordEagle Ford84 91 (8)%82 84 (2)%Eagle Ford156 84 86 %150 82 83 %
BakkenBakken114 107 %116 109 %Bakken108 114 (5)%102 116 (12)%
OklahomaOklahoma56 54 %54 54 — %Oklahoma50 56 (11)%52 54 (4)%
Northern Delaware20 24 (17)%20 25 (20)%
PermianPermian40 20 100 %43 20 115 %
Other United StatesOther United States29 %10 43 %Other United States(78)%10 (80)%
Total United StatesTotal United States283 283 — %282 279 %Total United States356 283 26 %349 282 24 %

Three Months Ended June 30, 2022Three Months Ended June 30, 2023
Sales Mix - U.S. Resource PlaysSales Mix - U.S. Resource PlaysEagle FordBakkenOklahomaNorthern DelawareTotalSales Mix - U.S. Resource PlaysEagle FordBakkenOklahomaPermianTotal
Crude oil and condensateCrude oil and condensate64 %66 %25 %51 %56 %Crude oil and condensate52 %63 %19 %53 %51 %
Natural gas liquidsNatural gas liquids18 %22 %32 %23 %23 %Natural gas liquids25 %23 %35 %25 %26 %
Natural gasNatural gas18 %12 %43 %26 %21 %Natural gas23 %14 %46 %22 %23 %

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Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
Drilling Activity - U.S. Resource PlaysDrilling Activity - U.S. Resource Plays2022202120222021Drilling Activity - U.S. Resource Plays2023202220232022
Gross OperatedGross OperatedGross Operated
Eagle Ford:Eagle Ford:Eagle Ford:
Wells drilled to total depthWells drilled to total depth32 23 62 53 Wells drilled to total depth30 32 65 62 
Wells brought to salesWells brought to sales19 45 47 70 Wells brought to sales49 19 85 47 
Bakken:Bakken:Bakken:
Wells drilled to total depthWells drilled to total depth10 17 24 39 Wells drilled to total depth27 10 45 24 
Wells brought to salesWells brought to sales20 16 40 19 Wells brought to sales23 20 40 40 
Oklahoma:Oklahoma:Oklahoma:
Wells drilled to total depthWells drilled to total depth— — — Wells drilled to total depth— 
Wells brought to salesWells brought to sales10 — 19 — Wells brought to sales— 10 19 
Northern Delaware:
Permian:Permian:
Wells drilled to total depthWells drilled to total depth— — Wells drilled to total depth14 
Wells brought to salesWells brought to sales— — — — Wells brought to sales— 16 — 
International
Net sales volumes were lower induring the second quarter of 2022three and six months ended June 30, 2023 as compared to the second quarter of 2021same period in the prior year primarily due to the impact of a turnaround completed in April 2023 and natural decline. The following table provides details regarding net sales volumes for our operations within this segment:
Three Months Ended June 30,Six Months Ended June 30,
Net Sales Volumes20222021Increase (Decrease)20222021Increase (Decrease)
Equivalent Barrels (mboed)
Equatorial Guinea60 65 (8)%60 66 (9)%
Equity Method Investees
LNG (mtd)
2,601 3,094 (16)%3,043 3,220 (5)%
Methanol (mtd)
964 744 30 %973 917 %
Condensate and LPG (boed)
10,363 7,892 31 %8,648 9,303 (7)%

Three Months Ended June 30,Six Months Ended June 30,
Net Sales Volumes20232022Increase (Decrease)20232022Increase (Decrease)
Equivalent Barrels (mboed)
Equatorial Guinea44 60 (27)%50 60 (17)%
Equity Method Investees
LNG (mtd)
1,716 2,601 (34)%1,913 3,043 (37)%
Methanol (mtd)
1,047 964 %1,212 973 25 %
Condensate and LPG (boed)
6,614 10,363 (36)%7,709 8,648 (11)%
Market Conditions
Commodity prices are the most significant factor impacting our revenues, profitability, operating cash flows, the amount of capital we invest in our business, redemption of our debt, payment of dividends and funding of share repurchases. BeginningCommodity prices experienced significant volatility in December 20202022 and continuing throughthis has continued into 2023. Russia’s invasion of Ukraine was a geopolitical shock that caused energy prices to spike significantly higher in early to mid-2022. However, Russian oil production has remained at higher levels than expected, European gas shortages were averted as record levels of LNG were imported into that market and an exceptionally warm winter in both the first six months of 2022, commodityUS and Europe has refilled gas inventories to multi year highs causing prices continued to increase duefall back significantly. Economic headwinds, caused by increasing interest rates as central banks continue to rising oilfight inflation, are a threat to demand growth as global economic activity increased. Higher commodity prices werewe move forward. In addition, demand growth in China will continue to have an impact as they emerge from strict COVID restrictions. Price volatility was also supportedexacerbated by ongoing OPECOPEC+ petroleum supply limitations conflicts and economic sanctions involving producer countries. We continue to expect commodity price volatility given the complex global dynamics of supply and demand that exist in the market including geopolitical events. Refe. Refer to Item 1A. Risk Factors in our 20212022 Annual Report on Form 10-K for further discussion on how volatility in commodity prices could impact us.    
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United States
The following table presents our average price realizations and the related benchmarks for crude oil and condensate, NGLs and natural gas for the second quarter and first six months of 20222023 and 2021.2022.
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
20222021Increase (Decrease)20222021Increase (Decrease)20232022Increase (Decrease)20232022Increase (Decrease)
Average Price Realizations(a)
Average Price Realizations(a)
Average Price Realizations(a)
Crude oil and condensate (per bbl)(b)
Crude oil and condensate (per bbl)(b)
$110.10 $64.73 70 %$102.29 $60.08 70 %
Crude oil and condensate (per bbl)(b)
$72.49 $110.10 (34)%$73.57 $102.29 (28)%
Natural gas liquids (per bbl)(c)
Natural gas liquids (per bbl)(c)
40.32 24.17 67 %38.84 24.06 61 %
Natural gas liquids (per bbl)(c)
18.72 40.32 (54)%21.25 38.84 (45)%
Natural gas (per mcf)(d)
6.84 2.61 162 %5.84 4.43 32 %
Natural gas (per mcf)(c)
Natural gas (per mcf)(c)
1.89 6.84 (72)%2.43 5.84 (58)%
BenchmarksBenchmarksBenchmarks
WTI crude oil average of daily prices (per bbl)
WTI crude oil average of daily prices (per bbl)
$108.52 $66.17 64 %$101.77 $62.22 64 %
WTI crude oil average of daily prices (per bbl)
$73.56 $108.52 (32)%$74.77 $101.77 (27)%
Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)
Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)
112.35 67.13 67 %104.51 63.22 65 %
Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)
74.93 112.35 (33)%76.14 104.51 (27)%
Mont Belvieu NGLs (per bbl)(e)(d)
Mont Belvieu NGLs (per bbl)(e)(d)
41.73 24.81 68 %39.99 24.40 64 %
Mont Belvieu NGLs (per bbl)(e)(d)
20.49 41.73 (51)%22.91 39.99 (43)%
Henry Hub natural gas settlement date average (per mmbtu)
Henry Hub natural gas settlement date average (per mmbtu)
7.17 2.83 153 %6.06 2.76 120 %
Henry Hub natural gas settlement date average (per mmbtu)
2.10 7.17 (71)%2.76 6.06 (54)%
(a)Excludes gains or losses on commodity derivative instruments.
(b)Inclusion of realized gains (losses) on crude oil derivative instruments would have decreased average price realizations by $4.43 per bbl and $5.54 per bbl for the second quarter 2022 and 2021, respectively.of 2022. Inclusion of realized gains (losses) on crude oil derivative instruments would have decreased average price realizations by $3.22 per bbl and $5.08 per bbl for the first six months of 2022 and 2021, respectively.2022.
(c)Inclusion of realized gains (losses) on NGL derivative instruments would have no impact for the second quarter 2022 and the second quarter 2021 would have decreased average price realizations by $1.15 per bbl. Inclusion of realized gains (losses) on NGL derivative instruments would have no impact per bbl for the first six months of 2022 and decreased average price realization by $1.24 for the six months ended 2021.
(d)Inclusion of realized gains (losses) on natural gas derivative instruments would have minimal impact on average price realizations for the second quarter and the first six months of 20222023 and 2021.2022.
(e)(d)Bloomberg Finance LLP: Y-grade Mix NGL of 55% ethane, 25% propane, 5% butane, 8% isobutane and 7% natural gasoline.
Crude oil and condensate Price realizations may differ from benchmarks due to the quality and location of the product.
Natural gas liquids The majority of our sales volumes are sold at reference to Mont Belvieu prices.
Natural gas A significant portion of our volumes are sold at bid-week prices, or first-of-month indices relative to our producing areas.
International (E.G.)    
The following table presents our average price realizations and the related benchmark for crude oil for the second quarter and first six months of 20222023 and 2021.2022.
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
20222021Increase (Decrease)20222021Increase (Decrease)20232022Increase (Decrease)20232022Increase (Decrease)
Average Price RealizationsAverage Price RealizationsAverage Price Realizations
Crude oil and condensate (per bbl)
Crude oil and condensate (per bbl)
$79.74 $52.78 51 %$71.14 $49.06 45 %
Crude oil and condensate (per bbl)
$53.64 $79.74 (33)%$56.46 $71.14 (21)%
Natural gas liquids (per bbl)
Natural gas liquids (per bbl)
1.00 1.00 — %1.00 1.00 — %
Natural gas liquids (per bbl)
1.00 1.00 — %1.00 1.00 — %
Natural gas (per mcf)
Natural gas (per mcf)
0.24 0.24 — %0.24 0.24 — %
Natural gas (per mcf)
0.24 0.24 — %0.24 0.24 — %
BenchmarkBenchmarkBenchmark
Brent (Europe) crude oil (per bbl)(a)
Brent (Europe) crude oil (per bbl)(a)
$113.54 $68.83 65 %$106.92 $64.83 65 %
Brent (Europe) crude oil (per bbl)(a)
$78.32 $113.54 (31)%$79.75 $106.92 (25)%
(a)Average of monthly prices obtained from the United States Energy Information Agency website.
Crude oil and condensate Alba field liquids production is primarily condensate. MEGPL and Marathon E.G. International LimitedWe generally sell theirour share of condensate in relation to the Brent crude benchmark. Alba Plant LLC processes the rich hydrocarbon gas which is supplied by the Alba field under a fixed-price long-termlong term contract. Alba Plant LLC extracts NGLs and secondary condensate which is then sold by Alba Plant LLC at market prices, with our share of the revenue reflected in income from equity method investments on the consolidated statements of income. Alba Plant LLC delivers the processed dry natural gas to the Alba Unit Parties for distribution and sale to AMPCO and EG LNG.
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Natural gas liquids Wet gas is sold to Alba Plant LLC at a fixed-price long-termlong term contract resulting in realized prices not tracking market price. Alba Plant LLC extracts and keeps NGLs, which are sold at market price, with our share of income from Alba Plant LLC being reflected in the income from equity method investments on the consolidated statements of income.
Natural gas Dry natural gas, processed by Alba Plant LLC on behalf of the Alba Unit Parties, is sold by the Alba field to EG LNG and AMPCO at fixed-price long-term contracts resulting in realized prices not tracking market price. The gas sales contracts between Alba Unit and EG LNG and AMPCO expire on December 31, 2023 and in 2026, respectively. We derive additional value from the equity investment in our downstream gas processing units EG LNG and AMPCO. EG LNG sells LNG on a market-based long-term contract and AMPCO markets methanol at market prices. In March 2023, we announced the signing of a HOA to progress the development of the Equatorial Guinea Regional Gas Mega Hub. The next phase involves processing Alba Unit gas under new contractual terms effective January 1, 2024, that would increase our exposure to global LNG market prices. In addition to processing Alba Unit gas, Alba Plant LLC and EG LNG process third partythird-party gas from the Alen field under a combination of a tolling and a market linked profit-sharing arrangement, the benefits of which are included in our respective share of income from equity method investees. This profit-sharing arrangement provides exposure to global LNG market prices.
Results of Operations
Three Months Ended June 30, 20222023 vs. Three Months Ended June 30, 20212022
Revenues from contracts with customers are presented by segment in the table below:
Three Months Ended June 30, Three Months Ended June 30,
(In millions)(In millions)20222021(In millions)20232022
Revenues from contracts with customersRevenues from contracts with customersRevenues from contracts with customers
United StatesUnited States$2,089 $1,189 United States$1,440 $2,089 
InternationalInternational79 65 International44 79 
Segment revenues from contracts with customersSegment revenues from contracts with customers$2,168 $1,254 Segment revenues from contracts with customers$1,484 $2,168 
Below is a price/volume analysis for each segment. Refer to the preceding Operations and Market Conditions sections for additional detail related to our net sales volumes and average price realizations.
Increase (Decrease) Related toIncrease (Decrease) Related to
(In millions)(In millions)Three Months Ended June 30, 2021Price RealizationsNet Sales VolumesThree Months Ended June 30, 2022(In millions)Three Months Ended June 30, 2022Price RealizationsNet Sales VolumesThree Months Ended June 30, 2023
United States Price/Volume AnalysisUnited States Price/Volume AnalysisUnited States Price/Volume Analysis
Crude oil and condensateCrude oil and condensate$936 $648 $(11)$1,573 Crude oil and condensate$1,573 $(620)$242 $1,195 
Natural gas liquidsNatural gas liquids131 96 12 239 Natural gas liquids239 (179)96 156 
Natural gasNatural gas91 142 (5)228 Natural gas228 (227)85 86 
Other sales31 49 
Other sales(a)
Other sales(a)
49 
TotalTotal$1,189 $2,089 Total$2,089 $1,440 
International Price/Volume AnalysisInternational Price/Volume AnalysisInternational Price/Volume Analysis
Crude oil and condensateCrude oil and condensate$58 $24 $(11)$71 Crude oil and condensate$71 $(19)$(13)$39 
Natural gas liquidsNatural gas liquids— (1)— Natural gas liquids— — — — 
Natural gasNatural gasNatural gas— (3)
Other salesOther salesOther sales
TotalTotal$65 $79 Total$79 $44 
(a)Includes revenue from commodity volumes purchased for resale.
Net gain (loss) on commodity derivatives in the second quarter of 2022,2023 was a lossnet gain of $27$3 million, compared to a net loss of $166$27 million for the same period in 2021.2022. We have multiple crude oil, natural gas and NGLcommodity derivative contracts thatwhich settle against various indices.the NYMEX WTI and Henry Hub indexes. We record commodity derivative gains/losses as the index pricing and forward curves change each period. See Note 1312 to the consolidated financial statements for further information.
Income from equity method investments increased $103 million in second quarter of 2022. Our investees benefited from higher price realizations in 2022.
Production expenses increased $38decreased $130 million in the second quarter of 2023, when compared to the second quarter of 2022, versusprimarily due to lower prices realized by our equity method investees during the second quarter of 2023, as well as lower production as a result of a turnaround at our E.G. facilities completed in April 2023.
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Production expenses increased $50 million in the second quarter of 2023, when compared to the same period in 2021,2022, primarily as a result of our acquisition of the U.S. segment’s higher project and workover activityEagle Ford assets of Ensign in December 2022 and inflationary pressures on labor, fuel, chemicals and services.when compared to the second quarter of 2022. In addition, in our International segment, production expenses were higher due to the April turnaround.



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The following table provides production expense and production expense rates (expense per boe) for each segment:
Three Months Ended June 30,Three Months Ended June 30,
($ in millions; rate in $ per boe)($ in millions; rate in $ per boe)20222021Increase (Decrease)20222021Increase (Decrease)($ in millions; rate in $ per boe)20232022Increase (Decrease)20232022Increase (Decrease)
Production Expense and RateProduction Expense and RateExpenseRateProduction Expense and RateExpenseRate
United StatesUnited States$150 $113 33 %$5.80 $4.41 32 %United States$191 $150 27 %$5.88 $5.80 %
InternationalInternational$14 $13 %$2.83 $2.17 30 %International$23 $14 64 %$5.72 $2.83 102 %
Shipping, handling and other operating increased $24decreased $30 million in the second quarter of 2022 versus2023 when compared to the same period in 2021. As disclosed in our Form 10-K, certain2022, primarily due to lower purchases of our processing arrangements with midstream entities are percentage-of-proceeds contracts. We classify the proceeds retained by the midstream companies as shipping and handling costs. The increase in shipping and handling costs of these percentage-of-proceeds contracts coincides with the increase in realized natural gas liquids and natural gas prices. In addition, higher marketing costs contributed to the increase as we purchased additionalcommodity volumes for resale to satisfy transportation commitments.
Exploration expensesinclude unproved property impairments, dry well costs, geological and geophysical and other costs.commitments as compared to the prior period. The decrease is partially offset by an increase in unproved property impairments is due tothird party consultant fees associated with a combinationnonrecurring Eagle Ford severance tax refund during the second quarter of factors including timing of lease expiration dates and decisions not to develop acreage deemed non-core in 2021. We incurred less amortization expense related to insignificant unproved property lease balances in 2022.2023.
The following table summarizes the components of exploration expenses:
 Three Months Ended June 30,
(In millions)20222021Increase (Decrease)
Exploration Expenses
Unproved property impairments$$22 (73)%
Dry well costs— — — %
Geological and geophysical— %
Other(50)%
Total exploration expenses$$25 (68)%
Depreciation, depletion and amortization decreased $96increased $123 million in the second quarter of 20222023 primarily as a result of lower DD&A (expense per boe) rate impacted by field-level changes in reserves. In addition, the DD&A rate is impacted by capitalized costs and the sales volume mix between fields.higher production volumes.
Our segments apply the units-of-production method to the majority of assets, including capitalized asset retirement costs; therefore, volumes have an impact on DD&A expense. The following table provides DD&A expense and DD&A expense rates for each segment:
Three Months Ended June 30,
($ in millions; rate in $ per boe)20222021Increase (Decrease)20222021Increase (Decrease)
DD&A Expense and RateExpenseRate
United States$415 $506 (18)%$16.11 $19.65 (18)%
International$16 $18 (11)%$2.80 $3.08 (9)%
Impairments decreased $44 million in the second quarter of 2022. Impairments in 2021 consisted of a $24 million impairment as we decommissioned certain Eagle Ford central facilities and a $22 million impairment related to an increase in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico. See Note 10 to the consolidated financial statements for discussion of the impairments in further detail.
Three Months Ended June 30,
($ in millions; rate in $ per boe)20232022Increase (Decrease)20232022Increase (Decrease)
DD&A Expense and RateExpenseRate
United States$547 $415 32 %$16.88 $16.11 %
International$10 $16 (38)%$2.42 $2.80 (14)%
Taxes other than income include production, severance and ad valorem taxes, primarily in the U.S., which tend to increase or decrease in relation to revenue and sales volumes. Taxes other than income increased $66decreased $97 million primarily due to higher price realizations in the U.S. segment in the second quarter of 2022.
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Loss on early extinguishment of debt decreased $19 million2023 primarily due to make-whole call provisions paid upon redemptiona nonrecurring Eagle Ford severance tax refund of $500$47 million in senior unsecured notesrelated to prior years and lower sales revenue in the second quarter of 2021.2023, when compared to the same period in 2022.
Provision (benefit) for income taxesNet interest and other reflects an effective income tax rate of 22%increased $38 million in the second quarter of 2022,2023 primarily as compared to an effective income tax ratea result of 38% in the second quarter of 2021.increased interest expense associated with borrowings on our Term Loan Facility and Revolving Credit Facility. SeeNote 614 to the consolidated financial statements for a more detailed discussion concerning the changesfurther information.
Provision for income taxes decreased $201 million in the effective tax rate.second quarter of 2023 primarily due to a decrease in income before income taxes for the current quarter when compared to the same period in 2022.
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Segment Income
Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs areSee Note 5 to the consolidated financial statements for further details regarding items not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, goodwill and equity method investments, changes in our valuation allowance, unrealized gains or losses on commodity and interest rate derivative instruments, effects of pension settlements and curtailments or other items (as determined by the chief operating decision maker (“CODM”)) are not allocated to operating segments.
The following table reconciles segment income (loss) to net income (loss):income:
Three Months Ended June 30, Three Months Ended June 30,
(In millions)(In millions)20222021(In millions)20232022
United StatesUnited States$846 $207 United States$365 $846 
InternationalInternational160 68 International30 160 
Segment income (loss)1,006 275 
Segment incomeSegment income395 1,006 
Items not allocated to segments, net of income taxesItems not allocated to segments, net of income taxes(40)(259)Items not allocated to segments, net of income taxes(108)(40)
Net income (loss)$966 $16 
Net incomeNet income$287 $966 
United States segment income (loss) in the second quarter of 20222023 was $846365 million of income versus a $207 million income for the same period in 2021. The increase in income was primarily due to higher price realizations and lower DD&A expenses. These favorable changes were partially offset by higher income taxes and production taxes in the second quarter of 2022.
International segment income (loss) in the second quarter of 2022 was$160 million of income versus $68$846 million of income for the same period in 2021,2022. The decrease in segment income is a result of the variances described above.
International segment income in the second quarter of 2023 was$30 million of income versus $160 million of income for the same period in 2022. The decrease was primarily due to higher prices realizedlower price realizations and lower net sales volume by our equity method investees.
Items not allocated to segments, net of income taxes in the second quarter of 2023 was a loss of $108 million versus a loss of $40 million for the same period in 2022. The increase was primarily due to unrealized net losses on commodity derivatives in the second quarter of 2023 versus unrealized net gains on commodity derivatives in the same period of 2022, as well higher interest expense as a result of outstanding borrowings on our Term Loan Facility and Revolving Credit Facility.
Results of Operations
Six Months Ended June 30, 20222023 vs. Six Months Ended June 30, 20212022
Revenues from contracts with customers are presented by segment in the table below:
 Six Months Ended June 30,
(In millions)20222021
Revenues from contracts with customers
United States$3,803 $2,321 
International126 110 
Segment revenues from contracts with customers$3,929 $2,431 






 Six Months Ended June 30,
(In millions)20232022
Revenues from contracts with customers
United States$2,943 $3,803 
International108 126 
Segment revenues from contracts with customers$3,051 $3,929 
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Below is a price/volume analysis for each segment. Refer to Operations and Market Conditions for additional detail related to our net sales volumes and average price realizations.
Increase (Decrease) Related toIncrease (Decrease) Related to
(In millions)(In millions)Six Months Ended June 30, 2021Price RealizationsNet Sales VolumesSix Months Ended June 30, 2022(In millions)Six Months Ended June 30, 2022Price RealizationsNet Sales VolumesSix Months Ended June 30, 2023
United States Price/Volume AnalysisUnited States Price/Volume AnalysisUnited States Price/Volume Analysis
Crude oil and condensateCrude oil and condensate$1,727 $1,202 $(15)$2,914 Crude oil and condensate$2,914 $(929)$395 $2,380 
Natural gas liquidsNatural gas liquids247 173 35 455 Natural gas liquids455 (269)139 325 
Natural gasNatural gas306 92 (19)379 Natural gas379 (317)163 225 
Other sales41 55 
Other sales(a)
Other sales(a)
55 13 
TotalTotal$2,321 $3,803 Total$3,803 $2,943 
International Price/Volume AnalysisInternational Price/Volume AnalysisInternational Price/Volume Analysis
Crude oil and condensateCrude oil and condensate$95 $35 $(19)$111 Crude oil and condensate$111 $(25)$10 $96 
Natural gas liquidsNatural gas liquids— (1)Natural gas liquids— — 
Natural gasNatural gas12 — — 12 Natural gas12 — (3)
Other salesOther salesOther sales
TotalTotal$110 $126 Total$126 $108 
(a)Includes revenue from commodity volumes purchased for resale.
Net gain (loss) on commodity derivativesin the first six months of 20222023 was a lossnet gain of $170$18 million, compared to a net loss of $319$170 million for the same period in 2021.2022. We have multiple crude oil, natural gas and NGLcommodity derivative contracts that settle against various indices.the NYMEX WTI and Henry Hub indexes. We record commodity derivative gains/losses as the index pricing and forward curves change each period. See Note 1312 to the consolidated financial statements for further information.
Income (loss) from equity method investments increased $186decreased $177 million for the first six months of 2022. Our2023, primarily as a result of lower prices realized by our equity method investees benefited from higher price realizations induring the first six months of 2022.2023.
Production expenses for the first six months of 20222023 increased by $69$99 million compared to the same period in 2021,2022, primarily as a result of our acquisition of the U.S. segment’s higher project and workover activityEagle Ford assets of Ensign in December 2022 and inflationary pressures on labor, fuel, chemicals and services.when compared to the same period of 2022. In addition, in our International segment, production expenses were higher due to the April turnaround.
The following table provides production expense and production expense rates for each segment:
Six Months Ended June 30,Six Months Ended June 30,
($ in millions; rate in $ per boe)($ in millions; rate in $ per boe)20222021Increase (Decrease)20222021Increase (Decrease)($ in millions; rate in $ per boe)20232022Increase (Decrease)20232022Increase (Decrease)
Production Expense and RateProduction Expense and RateExpenseRateProduction Expense and RateExpenseRate
United StatesUnited States$291 $224 30 %$5.70 $4.43 29 %United States$369 $291 27 %$5.85 $5.70 %
InternationalInternational$25 $23 %$2.37 $1.93 23 %International$46 $25 84 %$5.06 $2.37 114 %
Shipping, handling and other operating expenses increaseddecreased $5753 million in the first six months of 2022 from the comparable 2021 period. As disclosed in our Form 10-K, certain of our processing arrangements with midstream entities are percentage-of-proceeds contracts. We classify the proceeds retained by the midstream companies as shipping and handling cost. The increase in shipping and handling costs of these percentage-of-proceeds contracts coincides with the increase in realized natural gas liquids and natural gas prices. In addition, higher marketing costs contributed2023 when compared to the increase as we purchased additionalsame period in 2022, primarily due to lower purchases of commodity volumes for resale to satisfy transportation commitments.
Exploration expensesinclude unproved property impairments, dry well costs, geological and geophysical and other costs. The decreasecommitments in unproved property impairments is due2023 as compared to a combination of factors including timing of lease expiration dates and decisions not to develop acreage deemed non-core in 2021. We incurred less amortization expense related to insignificant unproved property lease balances in 2022.
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The following table summarizes the components of exploration expenses:
 Six Months Ended June 30,
(In millions)20222021Increase (Decrease)
Exploration Expenses
Unproved property impairments$14 $37 (62)%
Dry well costs— (100)%
Geological and geophysical(67)%
Other— %
Total exploration expenses$19 $46 (59)%
Depreciation, depletion and amortization decreased $169increased $220 million in the first six months of 20222023 primarily as a result of lower DD&A (expense per boe) rate impacted by field-level changes in reserves. In addition, the DD&A rate is impacted by capitalized costs and the sales volume mix between fields.higher production volumes.
Our segments apply the units-of-production method to the majority of their assets, including capitalized asset retirement costs; therefore volumes have an impact on DD&A expense. The following table provides DD&A expense and DD&A expense rates for each segment:
Six Months Ended June 30,
($ in millions; rate in $ per boe)20222021Increase (Decrease)20222021Increase (Decrease)
DD&A Expense and RateExpenseRate
United States$819 $978 (16)%$16.06 $19.36 (17)%
International$31 $37 (16)%$2.80 $3.09 (9)%
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Six Months Ended June 30,
($ in millions; rate in $ per boe)20232022Increase (Decrease)20232022Increase (Decrease)
DD&A Expense and RateExpenseRate
United States$1,052 $819 28 %$16.68 $16.06 %
International$22 $31 (29)%$2.41 $2.80 (14)%
ImpairmentsNet interest and other decreased $45increased $98 million in the first six months of 2022.Impairments in 2021 consisted2023 primarily as a result of a $24 million impairment as we decommissioned certain Eagle Ford central facilitiesincreased interest expense associated with borrowings on our Term Loan Facility and a $22 million impairment related to an increase in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico. See Note 10 to the consolidated financial statements for discussion of the impairments in further detail.Revolving Credit Facility.
Taxes other than income include production, severance and ad valorem taxes, primarily in the U.S., which tend to increase or decrease in relation to revenue and sales volumes. Taxes other than income increased $96decreased $106 million primarily due to higher price realizations in the U.S. segmentlower sales revenue in the first six months of 2022.2023, as well as a nonrecurring Eagle Ford severance tax refund of $47 million related to prior years in the second quarter of 2023.
General and administrative expensesProvision (benefit) for income taxes decreased $16 millionreflects an effective income tax rate of 21% in the first six months of 2023. The tax benefit for income taxes in the first six months of 2022 primarily due to expenses incurred in 2021 related to termination of an aircraft lease agreement.
Loss on early extinguishment of debt decreased $19 million due to make-whole call provisions paid upon redemption of $500 million in senior unsecured notes in 2021.
Provision (benefit) for income taxes for current year includesincluded a non-cash tax benefit of $685 million arising from the partial release of a valuation allowance on certain U.S. and state deferred tax assets in first quarter of 2022. This was partially offset by the provision related to current year income earned by our operations.assets. See Note 6 to the consolidated financial statements for a more detailed discussion concerning the rate changes.further information.
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Segment Income
Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs areSee Note 5 to the consolidated financial statements for further details regarding items not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, goodwill and equity method investments, changes in our valuation allowance, unrealized gains or losses on commodity and interest rate derivative instruments, effects of pension settlements and curtailments or other items (as determined by the chief operating decision maker (“CODM”)) are not allocated to operating segments.
The following table reconciles segment income (loss) to net income (loss):income:
Six Months Ended June 30, Six Months Ended June 30,
(In millions)(In millions)20222021(In millions)20232022
United StatesUnited States$1,507 $419 United States$790 $1,507 
InternationalInternational275 118 International119 275 
Segment income (loss)1,782 537 
Segment incomeSegment income909 1,782 
Items not allocated to segments, net of income taxesItems not allocated to segments, net of income taxes488 (424)Items not allocated to segments, net of income taxes(205)488 
Net income (loss)$2,270 $113 
Net incomeNet income$704 $2,270 
United States segment income (loss) for the first six months of 20222023 was $1,507$790 million of income versus a $419$1.5 billion of income for the same period in 2022. The decrease in segment income is a result of the variances described above.
International segment income for the first six months of 2023 was $119 million of income versus $275 million of income for the same period in 2021. This increase2022. The decrease was primarily due to higher price realizations and lower DD&A expenses. These favorable changes were partially offset by higher income taxes and production taxes in the first six months of 2022.
International segment income (loss) for the first six months of 2022 was $275 million of income versus $118 million of income for the same period in 2021,primarily due to higher prices realized by our equity method investees.
Items not allocated to segments, net of income taxes for the first six months of 20222023 was $205 million of loss versus $488 million of income versus a $424 million loss for the same period in 2021.2022. The increasechange from income to loss was primarily due to the first quarter 2022partial release of thea valuation allowance on certain U.S. and state deferred tax assets resultingin the first six months of 2022, which resulted in a non-cash deferred tax benefit of $685 million. In addition, we had increased interest expense as a result of outstanding borrowings on our Term Loan Facility and Revolving Credit Facility, partially offset by a decrease in unrealized net losses on commodity derivatives in the first six months of 2023.
Critical Accounting Estimates 
Other than the item set forth below, thereThere have been no material changes or developments in the evaluation of the accounting estimates and the underlying assumptions or methodologies pertaining to our Critical Accounting Estimates disclosed in our Form 10-K for the year ended December 31, 2021.
Income Taxes
We have recorded deferred tax assets and liabilities, measured at enacted tax rates, for temporary differences between book basis and tax basis, tax credit carryforwards and operating loss carryforwards. In accordance with U.S. GAAP, we routinely assess the realizability of our deferred tax assets and reduce such assets to the expected realizable amount by a valuation allowance if it is more likely than not that some portion or all of the deferred tax assets will not be realized. In assessing the need for additional or adjustments to existing valuation allowances, we consider all available positive and negative evidence. Positive evidence includes reversals of temporary differences, forecasts of future taxable income, assessment of future business assumptions and applicable tax planning strategies that are prudent and feasible. Negative evidence includes losses in recent years as well as the forecasts of future losses in the realizable period. In making our assessment regarding valuation allowances, we weight the evidence based on objectivity.
We base our future taxable income estimates on projected financial information which we believe to be reasonably likely to occur. Numerous judgments and assumptions are inherent in the estimation of future taxable income, including factors such as future operating conditions and the assessment of the effects of foreign taxes on our U.S. federal income taxes. Future operating conditions can be affected by numerous factors, including (i) future crude oil and condensate, NGLs and natural gas prices, (ii) estimated quantities of crude oil and condensate, NGLs and natural gas, (iii) expected timing of production, and (iv) future capital requirements. An estimate of the sensitivity to changes in assumptions resulting in future taxable income calculations is not practicable, given the numerous assumptions that can materially affect our estimates. Unfavorable adjustments to some of the above listed assumptions would likely be offset by favorable adjustments in other assumptions. For example, the impact of sustained reduced commodity prices on future taxable income would likely be partially offset by lower capital expenditures.2022.
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Based on the assumptions and judgments described above, during the first quarter of 2022, we re-evaluated the realizability of U.S. and state deferred tax assets and determined that a valuation allowance against certain deferred tax assets was no longer necessary. As such, we recorded a non-cash deferred tax benefit in the first quarter of 2022 for $685 million. See Note 6 to the consolidated financial statements for further detail.
Accounting Standards Not Yet Adopted
See Note 2 to the consolidated financial statements.
Cash Flows
    Commodity prices are the most significant factor impacting our revenues, profitability, operating cash flows, the amount of capital we invest in our business, principal debt repayments, payment of dividends and funding of share repurchases. We generated significant positive cash flow from operations during the first six months of 2022 given the continued improvement in commodity prices. We continue to expect volatility in commodity prices and that could impact how much cash flow from operations we generate. The following table presents sources and uses of cash and cash equivalents:
Six Months Ended June 30,Six Months Ended June 30,
(In millions)(In millions)20222021(In millions)20232022
Sources of cash and cash equivalentsSources of cash and cash equivalents  Sources of cash and cash equivalents  
Operating activities$2,745 $1,277 
Disposal of assets, net of cash transferred to the buyer15 
Net cash provided by operating activitiesNet cash provided by operating activities$1,941 $2,745 
Proceeds from revolving credit facilityProceeds from revolving credit facility980 — 
Borrowings(a)
Borrowings(a)
200 — 
Equity method investments - return of capitalEquity method investments - return of capital34 
OtherOther33 Other30 
Total sources of cash and cash equivalentsTotal sources of cash and cash equivalents$2,782 $1,298 Total sources of cash and cash equivalents$3,164 $2,782 
Uses of cash and cash equivalentsUses of cash and cash equivalentsUses of cash and cash equivalents
Additions to property, plant and equipmentAdditions to property, plant and equipment$(687)$(483)Additions to property, plant and equipment$(1,166)$(687)
Debt repayment(32)(500)
Debt extinguishment costs— (19)
Repayments of revolving credit facilityRepayments of revolving credit facility(980)— 
Debt repayment(a)
Debt repayment(a)
(270)(32)
Shares repurchased under buyback programsShares repurchased under buyback programs(1,352)— Shares repurchased under buyback programs(706)(1,352)
Dividends paidDividends paid(108)(55)Dividends paid(125)(108)
Purchases of shares for tax withholding obligationsPurchases of shares for tax withholding obligations(21)(9)Purchases of shares for tax withholding obligations(30)(21)
OtherOther— (4)Other(6)— 
Total uses of cash and cash equivalentsTotal uses of cash and cash equivalents$(2,200)$(1,070)Total uses of cash and cash equivalents$(3,283)$(2,200)
(a)Includes repayment and new borrowing associated with April 2023 remarketing to investors of $200 million sub-series 2017A-1 bonds. See Note 14 to the consolidated financial statements for further information.
Sources of cash and cash equivalents
Cash flows generated from operating activities during the second quarter of 2023 were 29% lower compared to 2022, primarily as a result of lower realized commodity prices, partially offset by higher volumes resulting from our acquisition of the Eagle Ford assets of Ensign in December 2022.
During the first six months of 2022 were significantly higher compared2023, we borrowed and repaid $980 million under our Revolving Credit Facility. See the Liquidity and Capital Resources section below for further information.
Uses of cash and cash equivalents
During the first six months of 2023, we repurchased approximately 29 million shares of our common stock pursuant to the same period in 2021, primarily asshare repurchase program at a resultcost of higher realized commodity prices.$706 million, paid dividends of $125 million and repaid the $70 million 8.5% Senior Notes on the maturity date. Additionally, we repurchased $30 million of shares during the first six months of 2023 related to our tax withholding obligations associated with the vesting of employee restricted stock awards and restricted stock units; these repurchases do not impact our share repurchase program authorization.
The following table shows capital expenditures by segment and reconciles to additions to property, plant and equipment as presented in the consolidated statements of cash flows:
Six Months Ended June 30,Six Months Ended June 30,
(In millions)(In millions)20222021(In millions)20232022
United StatesUnited States$718 $467 United States$1,217 $718 
InternationalInternational— International— 
Corporate
Not Allocated to Segments (Corporate)Not Allocated to Segments (Corporate)
Total capital expenditures (accrued)Total capital expenditures (accrued)723 473 Total capital expenditures (accrued)1,224 723 
Change in capital expenditure accrualChange in capital expenditure accrual(36)10 Change in capital expenditure accrual(58)(36)
Total use of cash and cash equivalents for property, plant and equipmentTotal use of cash and cash equivalents for property, plant and equipment$687 $483 Total use of cash and cash equivalents for property, plant and equipment$1,166 $687 
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The increase in our capital expenditures for the U.S. segment in the first six months of 20222023 compared to the same period in 20212022 was largely reflectsdriven by increased investment and drilling related to the Eagle Ford acreage we acquired from Ensign in December 2022. Additionally, inflationary pressures driven by the significant increase in cruderelated to oil field services, labor, drilling materials and natural gas prices,equipment, as well as a drillingtiming of capital spend and completion program more heavily weightedincreased activities in the first six months of 2023 compared to the first half ofsame period in 2022, contributed to the year.increase in capital expenditures.
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Liquidity and Capital Resources
Capital Resources and Available Liquidity
Our main sources of liquidity are cash and cash equivalents, internally generated cash flow from operations, sales of non-core assets, capital market transactions and our revolvingRevolving Credit Facility. During the second quarter of 2023, we obtained ratings for our commercial paper from Moody’s, Standard & Poor’s and Fitch. Pursuant to our U.S. commercial paper program, we may issue unsecured notes in a maximum aggregate face amount of $2.5 billion outstanding at any time, with maturities up to 365 days from the date of issuance. Our $2.5 billion U.S. commercial paper program is backed by our $2.5 billion Revolving Credit Facility and can be used to fund short-term working capital requirements. We did not issue commercial paper during the second quarter of 2023. At June 30, 2022,2023, we had approximately $4.3$2.3 billion of liquidity consisting of $1.2 billion$215 million in cash and cash equivalents and $3.1$2.1 billion available under our revolvingRevolving Credit Facility. On July 28, 2022, we executed the seventh amendment to our Credit Facility. The primary changes to the Credit Facility effected by this amendment were to (i) extend the maturity date of the Credit Facility by three years to July 28, 2027, (ii) decrease the size of the Credit Facility from $3.1 billion to $2.5 billion, (iii) replace the LIBOR interest rate benchmark with the secured overnight financing rate (“SOFR”) and (iv) implement certain revisions to the Pricing Schedule.
Our working capital requirements are supported by our cash and cash equivalents, U.S. commercial paper program and our Revolving Credit Facility. We may issue commercial paper, draw on our revolvingRevolving Credit Facility to meet short-term cash requirements or issue debt or equity securities through the shelf registration statement discussed below as part of our longer-term liquidity and capital management program. Because of the alternatives available to us as discussed above, we believe that our short-term and long-term liquidity are adequate to fund not only our current operations, but also our near-term and long-term funding requirements including our capital spending programs, defined benefit plan contributions, repayment of debt maturities, dividends and other amounts that may ultimately be paid in connection with contingencies. See Note 21 to the consolidated financial statements for further discussion of how our commitments and contingencies could affect our available liquidity. General economic conditions, commodity prices, and financial, business and other factors including the global pandemic, could affect our operations and our ability to access the capital markets.
We continue to be ratedmaintain investment grade ratings at all three primary credit rating agencies. A downgrade in our credit ratings could increase our future cost of financing or limit our ability to access capital and could result in additional credit support requirements. We do not have any triggers on any of our corporate debt that would cause an event of default in the case of a downgrade of our credit ratings. See Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 20212022 for a discussion of how a downgrade in our credit ratings could affect us.
We may incur additional debt in order to fund our working capital requirements, capital expenditures, acquisitions or development activities or for general corporate or other purposes. A higher level of indebtedness could increase the risk that our liquidity and financial flexibility deteriorates. See Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2022 for a further discussion of how our level of indebtedness could affect us.
Credit Arrangements and Borrowings
OurIn November 2022, we entered into a two-year $1.5 billion Term Loan Facility and borrowed the full amount thereunder in December 2022. The Term Loan Facility can be prepaid without penalty.
As of June 30, 2023, we had net borrowings of $450 million against our $2.5 billion Revolving Credit Facility includesand $5.9 billion of total long-term debt outstanding. Long-term debt due within one year consists of $131 million of 8.125% Senior Notes, which were repaid in connection with their maturity on July 17, 2023.
Both our Term Loan Facility and Revolving Credit Facility include a covenant requiring that our total debt to total capitalization ratio not exceed 65% as of the last day of the fiscal quarter. Our total debt-to-capital ratio was 19%26% at both June 30, 20222023 and 20% at December 31, 2021.2022. See Note 1514 to the consolidated financial statements for further information.
At June 30, 2022, we had no borrowings on our $3.1 billion Credit Facility and $4.0 billion of total long-term debt outstanding. In May 2022, we redeemed the $32 million 9.375% Senior Notes on the maturity date. Our next significant long-term debt maturity is in the amount of $1.0 billion due 2027. Refer to our 20212022 Annual Report on Form 10-K for a listing of our long-term debt maturities.
Shelf RegistrationOn April 3, 2023, we closed a $200 million remarketing to investors of sub-series 2017A-1 bonds that are part of the $1 billion St. John the Baptist, State of Louisiana revenue refunding bonds Series 2017. The bonds are subject to an interest rate of 4.05% and a mandatory purchase date of July 1, 2026.
Other sources of liquidity
We have aan effective universal shelf registration statement filed with the SEC underpursuant to which we, as a “well-known seasoned issuer” for purposes of SEC rules, have the abilitysubject to market conditions, are permitted to issue and sell an indeterminate
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amount of various types of debt, equity securities and equity securities.other capital instruments, if and when necessary or perceived by us to be opportune, in one or more public offerings. 
Capital Requirements
Share Repurchase Program
During the first six months of 2022, we repurchased approximately $1.4 billion of shares of our common stock. On May 4, 2022, ourOur Board of Directors increased our remaininghas authorized a share repurchase programprogram. Our remaining authorization to $2.5 billion. The total remaining share repurchase authorization was approximately $2.0 billion at June 30, 2022. Additionally, we repurchased $21 million of shares during the first six months of 2022 related to our tax withholding obligations associated with the vesting of employee restricted stock awards and restricted stock units; these repurchases do not impact our share repurchase program authorization.
Subsequent to the quarter, we repurchased2023 was approximately $282 million of shares of our common stock through August 3, 2022.$1.8 billion.
Dividends
On July 27, 2022,26, 2023, our Board of Directors approved a dividend of $0.08$0.10 per share payable September 12, 202211, 2023 to stockholders of record at the close of business on August 17, 2022.16, 2023.
Income Taxes

As described in
37


Note 6
to the consolidated financial statements, the IRA was signed into law during 2022. Under current law and guidance, we do not anticipate being subject to the corporate book minimum tax in 2023. The U.S. Treasury is expected to publish further guidance and regulations that will be relevant to scoping considerations and the calculation of minimum income tax liabilities. As this guidance is issued, we will continue to evaluate and assess the impact the IRA may have on our current and future period income taxes. If we conclude that we do trigger the minimum income tax, we may have to make estimated tax payments.
Other Contractual Cash Obligations
As of June 30, 2022,2023, there are no material changes to our consolidated cash obligations to make future payments under existing contracts, as disclosed in our 20212022 Annual Report on Form 10-K.
Environmental Matters and Other Contingencies
We have incurred and will continue to incur capital, operating and maintenance and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately offset by the prices we receive for our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas and production processes. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites. Penalties may be imposed for noncompliance.
Other than the items set forth in Part II - Item 1. Legal Proceedings, there have been no significant changes to the environmental, health and safety matters under Item 1. Business or Item 3. Legal Proceedings in our 20212022 Annual Report on Form 10-K. See Note 2221 to the consolidated financial statements for a description of other contingencies.

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Forward-Looking Statements
This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (the “Exchange Act”). All statements, other than statements of historical fact, including without limitation statements regarding our future performance, business strategy, 2022 capital budget and allocations, reserve estimates, asset quality, production guidance, drilling plans, capital plans, future debt retirement, cost and expense estimates, asset acquisitions and dispositions, expected impacts of the IRA, tax assumptions and allowances, future financial position, statements regarding future commodity prices, anticipated benefits of the Ensign acquisition, and statements regarding management’s other plans and objectives for future operations, are forward-looking statements. Words such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “outlook,” “plan,” “positioned,” “project,” “seek,” “should,” “target,” “will,” “would” or similar words may be used to identify forward-looking statements; however, the absence of these words does not mean that the statements are not forward-looking. While we believe that our assumptions concerning future events are reasonable, athese expectations may not prove to be correct. A number of factors could cause results to differ materially from those projected,indicated by such forward-looking statements including, but not limited to:
conditions in the oil and gas industry, including supply and demand levels for crude oil and condensate, NGLs and natural gas and the resulting impact on price;
changes in expected reserve or production levels;
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changes in political andor economic conditions in the U.S. and E.G., including changes in foreign currency exchange rates, interest rates, inflation rates and global and domestic market conditions;
actions taken by the members of OPEC and Russia affecting the production and pricing of crude oil;oil and other global and domestic political, economic or diplomatic developments;
capital available for exploration and development;
risks related to our hedging activities;
voluntary andor involuntary curtailments, delays or cancellations of certain drilling activities;
well production timing;
liabilities or corrective actions resulting from litigation, other proceedings and investigations or alleged violations of law or permits;
capital available for exploration and development;
the inability of any party to satisfy closing conditions or delays in execution with respect to our asset acquisitions and dispositions;
drilling and operating risks;
lack of, or disruption in, access to storage capacity, pipelines or other transportation methods;
well production timing;
availability of drilling rigs, materials and labor, including the costs associated therewith;
difficulty in obtaining necessary approvals and permits;
the availability, cost, terms and timing of issuance or execution of, competition for, and challenges to, mineral licenses and leases and governmental and other permits and rights-of-way, and our ability to retain mineral licenses and leases;
non-performance by third parties of their contractual or legal obligations, including due to bankruptcy;
administrative impediments or unexpected events that may impact dividends or other distributions, and the timing thereof, from our equity method investees;
changes in our credit ratings;
unforeseen hazards such as weather conditions, a health pandemic (including COVID-19), acts of war or terrorist acts and the governmental or military response thereto;
shortagesthe impacts of key personnel, including employees, contractorssupply chain disruptions that began during the COVID-19 pandemic and subcontractors;the resulting inflationary environment;
security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, or breaches of the information technology systems, facilities and infrastructure of third parties with which we transact business;
changes in safety, health, environmental, taxour ability to achieve, reach or otherwise meet initiatives, plans or ambitions with respect to ESG matters;
our ability to pay dividends and other regulationsmake share repurchases;
our ability to secure increased exposure to global LNG market prices;
impacts of the IRA;
the risk that the Ensign assets do not perform consistent with our expectations, including with respect to future production or requirements or initiatives including those addressing the impact of global climate change, air emissions or water management;drilling inventory;
other geological, operating and economic considerations; and
the risk factors, forward-looking statements and challenges and uncertainties described in our 20212022 Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and other filings with the SEC.
All forward-looking statements included in this report are based on information available to us on the date of this report. Except as required by law, we undertake no obligation to revise or update any forward-looking statements as a result of new information, future events or otherwise.
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Item 3. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to market risks in the normal course of business including commodity price risk and interest rate risk. We employ various strategies, including the use of financial derivatives to manage the risks related to commodity price and interest rate fluctuations. See Note 1312 and Note 1413 to the consolidated financial statements for detail relating to our open commodity derivative positions, including underlying notional quantities, how they are reported in our consolidated financial statements and how their fair values are measured.

Commodity Price Risk
As of June 30, 2022,2023, we had various open commodity derivatives.derivatives related to crude oil and natural gas. Based on the June 30, 20222023 published NYMEX WTI and natural gas futures prices, a hypothetical 10% change (per bbl for crude oil and per MMBtu for natural gas) would change the fair values of our commodity derivative positions to the following:
(In millions)Fair Value at June 30, 2022Hypothetical Price Increase of 10%Hypothetical Price Decrease of 10%
Derivative asset (liability) - Crude Oil$(81)$(119)$(51)
Derivative asset (liability) - Natural Gas(2)
Total$(79)$(121)$(44)

(In millions)Fair Value at June 30, 2023Hypothetical Price Increase of 10%Hypothetical Price Decrease of 10%
Derivative asset (liability) - Crude Oil$$(1)$
Derivative asset (liability) - Natural Gas$$$
Total$$$12 
Interest Rate Risk
At June 30, 2022,2023, our portfolio of current and long-term debt is comprised of floating rate debt and fixed-rate instruments. Our Term Loan Facility and Revolving Credit Facility are floating rate debt instruments, with anwhich expose us to the risk of earnings or cash flow losses as the result of potential increases in market interest rates. At June 30, 2023, we had $2.0 billion outstanding balanceborrowings under floating rate debt instruments. Assuming no change in the amount of $4.0 billion.floating rate debt outstanding, a hypothetical 100 basis point increase in the average interest rate under these borrowings would increase our annual interest expense by approximately $20 million. Actual results may vary due to changes in the amount of floating rate debt outstanding.
At June 30, 2023, we had $3.9 billion outstanding borrowings under fixed-rate debt instruments. Our sensitivity to interest rate movements and corresponding changes in the fair value of our fixed-rate debt portfolio affects our results of operations and cash flows only when we elect to repurchase or otherwise retire fixed-rate debt at prices different than carrying value.
At June 30, 2022,2023, we had forward starting interest rate swap agreements with a total notional amount of $295 million designated as cash flow hedges. We utilize cash flow hedges to manage our exposure to interest rate movements by utilizing interest rate swap agreements to hedge variations in cash flows related to the 1-month LIBORSOFR interest component of future lease payments on our Houston office. A hypothetical 10% change in interest rates would change the fair values of our cash flow hedgehedges to the following as of June 30, 2022:2023:
(In millions)(In millions)Fair Value at June 30, 2022Hypothetical Interest Rate Increase of 10%Hypothetical Interest Rate Decrease of 10%(In millions)
Fair Value at
June 30, 2023
Hypothetical Interest Rate Increase of 10%Hypothetical Interest Rate Decrease of 10%
Interest rate asset (liability) - designated as cash flow hedgesInterest rate asset (liability) - designated as cash flow hedges$16 $19 $13 Interest rate asset (liability) - designated as cash flow hedges$24 $28 $21 
Item 4. Controls and Procedures
An evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) was carried out under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer. As of the end of the period covered by this Report based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the design and operation of these disclosure controls and procedures were effective as of June 30, 2022.  2023.
During the first six months of 2022,2023, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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Part II – OTHER INFORMATION
Item 1. Legal Proceedings
In January 2020, weWe have received a Notice of ViolationNOV’s from the EPA related to allegations of violations of the Clean Air Act.Act with respect to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. We continue to actively negotiate a draft consent decree with the EPA and Department of Justice containing certain proposed injunctive terms relating to this enforcement action. The resolution of the enforcement action will likely include monetary sanctions and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. Given the uncertainty in matters suchWe maintain an accrual for estimated future costs related to this matter regarding actions required to retrofit or replace existing equipment, which we expect to incur over multiple years. Our accrual does not include possible monetary sanctions or costs associated with mitigation projects as these, we are currently unable to predict the ultimate outcome of this matter at this time. However,estimate those amounts. While we do not believe these enforcement actions wouldresolution of this matter will have a material adverse effect on our consolidated financial position, resultsbusiness or operations, there exists substantial uncertainty as to the ultimate result of operationsthis matter and it is reasonably possible the result could be materially different from our expectations and our accrual.
The Company received NOV’s from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 and 2022 over certain of the Company’s oil and gas facilities in New Mexico. The notices involve alleged emission and permitting violations. The Company has initiated discussions with the EPA to resolve these matters. As we are still investigating these allegations, we are unable to estimate the potential loss associated with these matters, however, it is reasonably possible that the resolution of these matters may result in a fine or cash flows.penalty in excess of $300,000.
Marathon Oil has been named in various lawsuits alleging royalty underpayments in our domestic operations. We intend to vigorously defend ourselves against such claims. For instance, Marathon Oil has beenwas named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and after plaintiffs have soughtlost their attempt to certify a class certification, whichaction, a settlement was reached, and in the first quarter of 2023 such settlement was approved by the court has so far denied. We have accrued for potential liabilities associated with these lawsuits based on currently available information; however, actual losses may exceed our accruals or we could be required to accrue additional amounts in the future.and paid.
Other than the items set forth above, there have been no significant changes to Item 3. Legal Proceedings in our 20212022 Annual Report on Form 10-K. See Note 2221 to the consolidated financial statements included in Part I, Item I for a description of such legal and administrative proceedings and Item 3. Legal Proceedings in our 20212022 Annual Report on Form 10-K.
Item 1A. Risk Factors
We are subject to various risks and uncertainties in the course of our business. In addition to the other information set forth in this Quarterly Report on Form 10-Q, the reader should carefully consider the factors discussed in Item 1A. Risk Factors in our 20212022 Annual Report on Form 10-K. Other than the risk factor set forth below, thereThere have been no material changes or updates to the risk factors from those listed in Item 1A. Risk Factorspreviously disclosed in our 20212022 Annual Report on Form 10-K.
Our sector and the broader US economy have experienced higher than expected inflationary pressures in the first six months of 2022, related to continued supply chain disruptions, labor shortages and geopolitical instability. Should these conditions persist, it may impact our ability to procure materials and equipment on a cost-effective basis, or at all, and, as a result, our business, results of operations and cash flows could be materially and adversely affected.
Throughout the first six months of 2022, we have experienced significant increases in the costs of certain materials, including steel, sand and fuel, as a result of availability constraints, supply chain disruption, increased demand, labor shortages associated with a fully employed US labor force, inflation and other factors. Though we incorporated inflationary factors into our 2022 business plan, inflation has outpaced those original assumptions. These challenges are due in large measure to increased demand for oil and gas production driven by the continued economic recovery from the COVID-19 pandemic and more broadly, systemic underinvestment in global oil and gas development. These supply and demand fundamentals have been further aggravated by disruptions in global energy supply caused by multiple geopolitical events, including the ongoing conflict between Russia and Ukraine. We continue to undertake actions and implement plans to strengthen our supply chain to address these pressures and protect the requisite access to commodities and services. Nevertheless, we expect for the foreseeable future to experience supply chain constraints and inflationary pressure on our cost structure. These supply chain constraints and inflationary pressures will likely continue to adversely impact our operating costs and if we are unable to manage our global supply chain, it may impact our ability to procure materials and equipment in a timely and cost-effective manner, if at all, which could result in reduced margins and production delays and, as a result, our business, financial condition, results of operations and cash flows could be materially and adversely affected.
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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table provides information about purchases by Marathon Oil, during the quarter ended June 30, 20222023, of equity securities that are registered by Marathon Oil pursuant to Section 12 of the Securities Exchange Act of 1934:1934.
Period
Total Number of Shares Purchased(a)
Average Price Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(b)
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(b)
04/01/2022 - 04/30/20229,548,422 $25.66 9,548,422 $1,140,310,932 
05/01/2022 - 05/31/20229,636,905 $26.69 9,636,905 $2,304,000,254 
06/01/2022 - 06/30/20229,300,166 $27.66 9,299,310 $2,046,750,659 
Total28,485,493 $26.66 28,484,637 
Period
Total Number of Shares Purchased(a)
Average Price Paid per Share(b)
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(c)
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(b)(c)
04/01/2023 - 04/30/20233,811,086 $24.93 3,811,086 $2,041,000,432 
05/01/2023 - 05/31/20235,853,037 $22.98 5,853,037 $1,906,501,938 
06/01/2023 - 06/30/20236,173,567 $22.96 6,173,567 $1,764,769,042 
Total15,837,690 $23.44 15,837,690 
(a)856No shares of restricted stock were delivered by employees to Marathon Oil, upon vesting, to satisfy tax withholding requirements.
(b)Excludes 1% excise tax on share repurchases.
(c)Refer to our 20212022 Annual Report on Form 10-K for historical share repurchase program authorizations and repurchase activity through December 31, 2021. In May 2022, our Board of Directors increased the authorization of repurchases under the program to $2.5 billion.2022. As of June 30, 2022,2023, we have $2.0approximately $1.8 billion of authorization remaining under the share repurchase program. Purchases under the program are made at our discretion and may be in either open market transactions, including block purchases or in privately negotiated transactions using cash on hand, cash generated from operations or proceeds from potential asset sales. This program may be changed based upon our financial condition or changes in market conditions and is subject to termination prior to completion. Shares repurchased as of June 30, 20222023, were held as treasury stock.
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Item 5. Other Information
During the three months ended June 30, 2023, no director or officer adopted or terminated a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as each term is defined in Item 408(a) of Regulation S-K.
Item 6. Exhibits
The information required by this Item 6 is set forth in the Exhibit Index accompanying this Form 10-Q.
  Incorporated by Reference
(File No. 001-05153, unless otherwise indicated)
Exhibit NumberExhibit DescriptionFormExhibitFiling Date
3.18-K3.16/1/2018
3.210-Q3.28/4/2016
3.310-K3.32/28/2014
4.110-K4.22/28/2014
31.1*
31.2*
32.1**
32.2**
101.INS*XBRL Instance Document - the XBRL Instance Document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH*XBRL Taxonomy Extension Schema
101.CAL*XBRL Taxonomy Extension Calculation Linkbase
101.DEF*XBRL Taxonomy Extension Definition Linkbase
101.LAB*XBRL Taxonomy Extension Label Linkbase
101.PRE*XBRL Taxonomy Extension Presentation Linkbase
104*
Cover Page Interactive Data File, formatted in iXBRL and contained in Exhibit 101
*Filed herewith.
**
Furnished herewith. This certification will be treated as “accompanying” this report and not “filed” as part of
such report for purposes of Section 18 of the Exchange Act or otherwise subject to the liability of Section 18
of the Exchange Act.
Management contract or compensatory plan or arrangement.
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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.
August 4, 20223, 2023MARATHON OIL CORPORATION
  
 By:/s/ Rob L. White
 Rob L. White
 Vice President, Controller and Chief Accounting Officer
(Duly Authorized Officer)
4341


Exhibit Index
  Incorporated by Reference
(File No. 001-05153, unless otherwise indicated)
Exhibit NumberExhibit DescriptionFormExhibitFiling Date
3.18-K3.16/1/2018
3.210-Q3.28/4/2016
3.310-K3.32/28/2014
4.110-K4.22/28/2014
10.18-K10.18/2/2022
31.1*
31.2*
32.1*
32.2*
101.INS*XBRL Instance Document - the XBRL Instance Document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH*XBRL Taxonomy Extension Schema
101.CAL*XBRL Taxonomy Extension Calculation Linkbase
101.DEF*XBRL Taxonomy Extension Definition Linkbase
101.LAB*XBRL Taxonomy Extension Label Linkbase
101.PRE*XBRL Taxonomy Extension Presentation Linkbase
104*
Cover Page Interactive Data File, formatted in iXBRL and contained in Exhibit 101
*Filed herewith.