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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 Ended	~~March~~June 3130, 2024


☐			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 1-5153

Marathon Oil Corporation

(Exact name of registrant as specified in its charter)


Delaware						25-0996816
(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 Symbol

Name of each exchange on which registered

Common Stock, par value $1.00

MRO

New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes 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 filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. 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 ~~564~~559,~~035~~383,~~502~~423 shares of Marathon Oil Corporation common stock outstanding as of ~~April~~July 3031, 2024.

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 2023 Annual Report on Form 10-K.

	Table of Contents
		Page
Part I - FINANCIAL INFORMATION
Item 1.	Financial Statements:
	Consolidated Statements of Income (Unaudited)	2
	Consolidated Statements of Comprehensive Income (Unaudited)	3
	Consolidated Balance Sheets (Unaudited)	4
	Consolidated Statements of Cash Flows (Unaudited)	5
	Consolidated Statements of Stockholders' Equity (Unaudited)	6
	Notes to Consolidated Financial Statements (Unaudited)	7
	1. Basis of Presentation	7
	1. Organization and Basis of Presentation	7
	2. Accounting Standards	7
	3. Income and Dividends per Common Share	78
	4. Revenues	78
	5. Segment Information	810
	6. Income Taxes	1115
	7. Debt	1115
	8. Derivatives	1216
	9. Fair Value Measurements	1419
	10. Property, Plant and Equipment	1520
	11. Asset Retirement Obligations	1621
	12. Equity Method Investments	1621
	13. Stockholders' Equity	1722
	14. Incentive Based Compensation	1823
	15. Inventories	1824
	16. Supplemental Cash Flow Information	1824
	17. Commitments and Contingencies	1924
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	2127
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3242
Item 4.	Controls and Procedures	3242
Part II - OTHER INFORMATION
Item 1.	Legal Proceedings	3343
Item 1A.	Risk Factors	3343
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3345
Item 5.	Other Information	3345
Item 6.	Exhibits	3446
	Signatures	3547

Table of Contents

Part I – FINANCIAL INFORMATION

Item 1. Financial Statements

MARATHON OIL CORPORATION

Consolidated Statements of Income (Unaudited)

	Three Months Ended				Six Months Ended
	March 31,
	June 30,				June 30,
(In millions, except per share data)	2024		2023		2024		2023
Revenues and other income:
Revenues from contracts with customers	$	1,~~538~~666	$	1,~~567~~484	$	3,204	$	3,051
Net gain (loss) on commodity derivatives	~~(24)~~1		153		(23)		18
Income from equity method investments	3926		8022		65		102
Net gain on disposal of assets	—10		5—		10		5
Other income (expense)	(2)		13
Other income	4		4		2		17
Total revenues and other income	1,~~551~~707		1,~~680~~513		3,258		3,193
Costs and expenses:
Production	~~221~~216		~~201~~214		437		415
Shipping, handling and other operating, including related party of $15 and $0	169		162
Shipping, handling and other operating, including related party of $12, $0, $27 and $0	175		161		344		323
Exploration	714		1511		21		26
Depreciation, depletion and amortization	~~524~~577		~~520~~559		1,101		1,079
Taxes other than income	96103		9543		199		138
General and administrative	8699		8271		185		153
Total costs and expenses	1,~~103~~184		1,~~075~~059		2,287		2,134
Income from operations	~~448~~523		~~605~~454		971		1,059
Net interest and other	(6980)		(8292)		(149)		(174)
Other net periodic benefit credits	32		3		5		6
Income before income taxes	~~382~~445		~~526~~365		827		891
Provision for income taxes	8596		~~109~~78		181		187
Net income	$	~~297~~349	$	~~417~~287	$	646	$	704
Net income per share:
Basic	$	0.5262	$	0.6647	$	1.13	$	1.13
Diluted	$	0.5262	$	0.6647	$	1.13	$	1.13
Weighted average common shares outstanding:
Basic	~~576~~566		~~628~~614		573		622
Diluted	~~576~~567		~~629~~615		574		623

The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

MARATHON OIL CORPORATION

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended				Six Months Ended
	March 31,
	June 30,				June 30,
(In millions)	2024		2023		2024		2023
Net income	$	~~297~~349	$	~~417~~287	$	646	$	704
Other comprehensive loss, net of tax
Change in actuarial gain and other for postretirement and postemployment plans	(4)		(5)
Postretirement and postemployment plans	(2)		(8)		(6)		(13)
Change in derivative hedges unrecognized gain	2		(2)
Change in derivative hedges unrecognized gain (loss)	(1)		3		1		1
Other comprehensive loss	(23)		(75)		(5)		(12)
Comprehensive income	$	~~295~~346	$	~~410~~282	$	641	$	692

The accompanying notes are an integral part of these consolidated financial statements.

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MARATHON OIL CORPORATION

Consolidated Balance Sheets (Unaudited)

	March 31,		December 31,
	June 30,		December 31,
(In millions, except par value and share amounts)	2024		2023
Assets
Current assets:
Cash and cash equivalents	$	4977	$	155
Receivables, net	1,~~276~~340		1,152
Inventories	~~179~~161		186
Other current assets	5341		76
Total current assets	1,~~557~~619		1,569
Equity method investments	~~472~~421		433
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $26,420 and $25,914	17,303		17,213
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $26,982 and $25,914	17,387		17,213
Other noncurrent assets	~~336~~313		360
Total assets	$	19,~~668~~740	$	19,575
Liabilities
Current liabilities:
Accounts payable	$	1,~~514~~564	$	1,364
Commercial paper	~~450~~325		450
Payroll and benefits payable	4071		70
Accrued taxes	~~135~~151		126
Other current liabilities	~~310~~319		312
Long-term debt due within one year	400		1,600
Total current liabilities	2,~~849~~830		3,922
Long-term debt	4,~~578~~572		3,378
Deferred tax liabilities	~~462~~477		419
Defined benefit postretirement plan obligations	9394		93
Asset retirement obligations	~~329~~336		326
Deferred credits and other liabilities	~~213~~225		232
Total liabilities	8,~~524~~534		8,370
Commitments and contingencies (Note 17)
Stockholders’ Equity
Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	—		—
Common stock:
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at March 31, 2024 and December 31, 2023)	937		937
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at June 30, 2024 and December 31, 2023)	937		937
Held in treasury, at cost – 369 million shares and 360 million shares	(9,201)		(8,952)
Held in treasury, at cost – 378 million shares and 360 million shares	(9,434)		(8,952)
Additional paid-in capital	7,~~129~~141		7,172
Retained earnings	12,~~199~~485		11,966
Accumulated other comprehensive income	8077		82
Total stockholders’ equity	11,~~144~~206		11,205
Total liabilities and stockholders’ equity	$	19,~~668~~740	$	19,575

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)

	Three Months Ended
	Six Months Ended
	March 31,
	June 30,
(In millions)	2024		2023
Increase (decrease) in cash and cash equivalents
Operating activities:
Net income	$	~~297~~646	$	~~417~~704
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	~~524~~1,101		~~520~~1,079
Exploratory dry well costs and unproved property impairments	618		1424
Net gain on disposal of assets	—(10)		(5)
Deferred income taxes	4359		85155
Unrealized (gain) loss on derivative instruments, net	24		(2)
Unrealized loss on derivative instruments, net	23		2
Pension and other post retirement benefits, net	(37)		(711)
Stock-based compensation	1124		1021
Equity method investments, net	~~(39)~~10		~~(80)~~113
Changes in:
Current receivables	(~~120~~185)		(86158)
Inventories	624		(1211)
Current accounts payable and accrued liabilities	12107		3037
Other current assets and liabilities	~~(2)~~10		~~(9)~~10
All other operating, net	~~(2)~~25		(1019)
Net cash provided by operating activities	~~757~~1,845		~~865~~1,941
Investing activities:
Capital expenditures	(~~603~~1,268)		(~~601~~1,224)
Change in capital accrual	~~117~~136		6958
Acquisitions, net of cash acquired	(4)		119
Disposal of assets, net of cash transferred to the buyer	—11		(1)
All other investing, net	1		—
Equity method investments - return of capital	2		34
Net cash used in investing activities	(489)		(522)
All other investing, net	—		(1)
Net cash used in investing activities	(1,123)		(1,125)
Financing activities:
Borrowings	1,200		—200
Debt repayments	(1,200)		(70270)
Proceeds from revolving credit facility	50		~~175~~980
Repayments of revolving credit facility	(4350)		(~~175~~980)
Shares repurchased under buyback programs	(285)		(334)
Repayments of commercial paper borrowings, net	(125)		—
Dividends paid	(64)		(63)
Shares repurchased under buyback programs	(516)		(706)
Dividends paid	(127)		(125)
Withholding tax on stock-based incentive awards	(18)		(30)
All other financing, net	(14)		(24)
Net cash used in financing activities	(~~374~~800)		(~~499~~935)
Net decrease in cash and cash equivalents	(~~106~~78)		(~~156~~119)
Cash and cash equivalents at beginning of period	155		334
Cash and cash equivalents at end of period	$	4977	$	~~178~~215

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
(In millions)	PreferredStock		CommonStock		TreasuryStock		AdditionalPaid-inCapital		RetainedEarnings		AccumulatedOtherComprehensiveIncome		TotalEquity
Three Months Ended March 31, 2023
Six Months Ended June 30, 2023
December 31, 2022 Balance	$	—	$	937	$	(7,512)	$	7,203	$	10,663	$	106	$	11,397
Shares repurchased under buyback programs	—		—		(334)		—		—		—		(334)
Excise tax on shares repurchased	—		—		(3)		—		—		—		(3)
Stock-based compensation	—		—		35		(54)		—		—		(19)
Net income	—		—		—		—		417		—		417
Other comprehensive loss	—		—		—		—		—		(7)		(7)
Dividends paid (per share amount of $0.10)	—		—		—		—		(63)		—		(63)
March 31, 2023 Balance	$	—	$	937	$	(7,814)	$	7,149	$	11,017	$	99	$	11,388
Three Months Ended March 31, 2024
Shares repurchased under buyback programs	—		—		(372)		—		—		—		(372)
Excise tax on shares repurchased	—		—		(3)		—		—		—		(3)
Stock-based compensation	—		—		1		10		—		—		11
Net income	—		—		—		—		287		—		287
Other comprehensive loss	—		—		—		—		—		(5)		(5)
Dividends paid (per share amount of $0.10)	—		—		—		—		(62)		—		(62)
June 30, 2023 Balance	$	—	$	937	$	(8,188)	$	7,159	$	11,242	$	94	$	11,244
Six Months Ended June 30, 2024
December 31, 2023 Balance	$	—	$	937	$	(8,952)	$	7,172	$	11,966	$	82	$	11,205
Shares repurchased under buyback programs	—		—		(285)		—		—		—		(285)
Excise tax on shares repurchased	—		—		(2)		—		—		—		(2)
Stock-based compensation	—		—		38		(43)		—		—		(5)
Net income	—		—		—		—		297		—		297
Other comprehensive loss	—		—		—		—		—		(2)		(2)
Dividends paid (per share amount of $0.11)	—		—		—		—		(64)		—		(64)
March 31, 2024 Balance	$	—	$	937	$	(9,201)	$	7,129	$	12,199	$	80	$	11,144
Shares repurchased under buyback programs	—		—		(231)		—		—		—		(231)
Excise tax on shares repurchased	—		—		(3)		—		—		—		(3)
Stock-based compensation	—		—		1		12		—		—		13
Net income	—		—		—		—		349		—		349
Other comprehensive loss	—		—		—		—		—		(3)		(3)
Dividends paid (per share amount of $0.11)	—		—		—		—		(63)		—		(63)
June 30, 2024 Balance	$	—	$	937	$	(9,434)	$	7,141	$	12,485	$	77	$	11,206

The accompanying notes are an integral part of these consolidated financial statements.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

1. Organization and Basis of Presentation

We are an independent oil and gas exploration and production company with a focus on U.S. resource plays: Eagle Ford in Texas, Bakken in North Dakota, Permian in New Mexico and Texas and STACK and SCOOP in Oklahoma. Our U.S. assets are complemented by our international operations in E.G.

Proposed Merger with ConocoPhillips

On May 28, 2024, we entered into an Agreement and Plan of Merger (the “Merger Agreement”) with ConocoPhillips, a Delaware corporation (“ConocoPhillips”), and Puma Merger Sub Corp., a wholly owned subsidiary of ConocoPhillips (“Merger Sub”). The Merger Agreement provides that, among other things and subject to the terms and conditions of the Merger Agreement, Merger Sub be merged with and into Marathon Oil (the “Merger”), with Marathon Oil surviving and continuing as the surviving corporation in the Merger as a direct, wholly owned subsidiary of ConocoPhillips. Under the terms of the Merger Agreement, at the effective time of the Merger (the “Effective Time”), each of our outstanding shares of common stock (other than certain Excluded Shares and Converted Shares, each as defined in the Merger Agreement) will be converted to the right to receive 0.2550 (the “Exchange Ratio”) shares of ConocoPhillips common stock (the “Merger Consideration”). The Merger Agreement also contains certain customary termination rights of each of Marathon Oil and ConocoPhillips, and under certain circumstances, a termination fee would be payable by us. The Merger is expected to close late in the fourth quarter of 2024, subject to shareholder and regulatory approvals and other customary closing conditions; however, no assurance can be given as to when, or if, the Merger will occur. See Item 1A. Risk Factors for a discussion of the risks related to the Merger and Item 2. Manag ement ’s Discussion and Analysis of Financial Condition and Results of Operations for additional details relating to the Merger.

In association with the Merger, we have incurred $10 million of transaction costs recorded as general and administrative expense in the consolidated statements of income for the three and six months ended June 30, 2024, and expect to incur additional costs as the Merger progresses. Transaction costs consist primarily of third party legal and banking fees.

The above description of the Merger Agreement and the transactions contemplated thereby, including certain referenced terms, is a summary of certain principal terms and conditions contained in the Merger Agreement.

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 2023 Annual Report on Form 10-K. The results of operations for the ~~first~~second quarter and first six months of 2024 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 induring the first ~~quarter~~six months of 2024 that had a material impact on our consolidated financial statements.

Accounting Standards Updates Not Yet Adopted

~~There~~In ~~were~~November no2023, the FASB issued ~~but~~a ~~pending~~new accounting standards ~~expected~~update to ~~have~~improve the disclosures around a ~~material~~public entity’s reportable segments. The standard requires disclosure of significant segment expenses included within each reported measure of segment profit or loss. This standard is effective for annual reporting periods beginning after December 15, 2023, and interim reporting periods within annual reporting periods beginning after December 15, 2024, with early adoption permitted. The standard is effective for us in the 2024 annual reporting period and will be applied retrospectively to all prior periods presented in the financial statements. This standard only modifies disclosure requirements; as such, there will be no impact on our consolidated results of operations, financial ~~statements~~position or cash flows.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

In December 2023, the FASB issued a new accounting standards update to improve income tax disclosures primarily related to the rate reconciliation and income taxes paid. The standard requires consistent categories and greater disaggregation of information in the rate reconciliation and income taxes paid by jurisdiction. The standard is effective for annual periods beginning after December 15, 2024, with early adoption permitted. This standard is effective for us in the 2025 annual reporting period and will be applied retrospectively to all prior periods presented in the financial statements. The standard only modifies disclosure requirements; as such, there will be no impact on our consolidated results of operations, financial position or cash flows.

There were no other 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 and performance units in all periods, provided the effect is not antidilutive. The per share calculations below exclude 1an ~~million~~immaterial number of antidilutive stock options for the three months ended June 30, 2024 and ~~performance~~exclude ~~units~~1 ~~for~~million ~~both~~of antidilutive stock options for the ~~three~~six months ended ~~March~~June 3130, 2024. In addition, the per share calculations below exclude 1 million of antidilutive stock options for the three months and six months ended June 30, 2023:

	Three Months Ended March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
(In millions, except per share data)	2024		2023		2024		2023
Net income	$	~~297~~349	$	~~417~~287	$	646	$	704
Weighted average common shares outstanding	~~576~~566		~~628~~614		573		622
Effect of dilutive securities	—1		1		1		1
Weighted average common shares, diluted	~~576~~567		~~629~~615		574		623
Net income per share:
Basic	$	0.5262	$	0.6647	$	1.13	$	1.13
Diluted	$	0.5262	$	0.6647	$	1.13	$	1.13
Dividends per share	$	0.11	$	0.10	$	0.22	$	0.20

Under the Merger Agreement, we are subject to restrictions that prevent us from increasing our quarterly dividend in excess of $0.11 per share.

4. Revenues

The majority of our revenues are derived from the sale of crude oil and condensate, NGLs and natural gas, including LNG, under spot and term agreements with our customers in the United States and Equatorial Guinea.

As of ~~March~~June 3130, 2024 and December 31, 2023, receivables from contracts with customers, included in receivables, ~~less reserves for credit losses~~net, were $~~972~~1.0 ~~million~~billion and $886 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 ~~March~~June 3130:

United States

	Three Months Ended March 31, 2024
	Three Months Ended June 30, 2024
(In millions)	Eagle Ford		Bakken		Permian		Oklahoma		Other U.S.		Total
Crude oil and condensate	$	~~439~~582	$	~~465~~482	$	~~199~~191	$	6549	$	12	$	1,~~180~~316
NGLs	5867		4145		2021		3230		—		~~151~~163
Natural gas	3331		1611		72		2921		1—		8665
Other	12		—		—		—		45		57
Revenues from contracts with customers	$	~~531~~682	$	~~522~~538	$	~~226~~214	$	~~126~~100	$	17	$	1,~~422~~551

	Three Months Ended March 31, 2023
	Three Months Ended June 30, 2023
(In millions)	Eagle Ford		Bakken		Permian		Oklahoma		Other U.S.		Total
Crude oil and condensate	$	~~495~~524	$	~~431~~456	$	~~170~~141	$	7863	$	11	$	1,~~185~~195
NGLs	7164		3741		2218		3933		—		~~169~~156
Natural gas	5637		3514		117		3628		1—		~~139~~86
Other	21		—		—		—		82		103
Revenues from contracts with customers	$	~~624~~626	$	~~503~~511	$	~~203~~166	$	~~153~~124	$	2013	$	1,~~503~~440

	Three Months Ended March 31,
	Six Months Ended June 30, 2024
(In millions)	~~2024~~Eagle Ford		~~2023~~Bakken		Permian		Oklahoma		Other U.S.		Total
Crude oil and condensate	$	611,021	$	57947	$	390	$	114	$	24	$	2,496
NGLs	1125		186		41		62		—		314
Natural gas, sold as gas	2		5
Natural gas	64		27		9		50		1		151
Natural gas, sold as LNG	51		—
Other	3		—		—		—		9		12
Natural gas, total	53		5
Revenues from contracts with customers	$	1,213	$	1,060	$	440	$	226	$	34	$	2,973
Other	1		1
Revenues from contracts with customers	$	116	$	64


	Six Months Ended June 30, 2023
(In millions)	Eagle Ford		Bakken		Permian		Oklahoma		Other U.S.		Total
Crude oil and condensate	$	1,019	$	887	$	311	$	141	$	22	$	2,380
NGLs	135		78		40		72		—		325
Natural gas	93		49		18		64		1		225
Other	3		—		—		—		10		13
Revenues from contracts with customers	$	1,250	$	1,014	$	369	$	277	$	33	$	2,943

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

International (E.G.)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2024		2023		2024		2023
Crude oil and condensate	$	28	$	39	$	89	$	96
NGLs	—		—		1		1

Natural gas, sold as gas	2		4		4		9
Natural gas, sold as LNG	84		—		135		—
Natural gas, total	86		4		139		9
Other	1		1		2		2
Revenues from contracts with customers	$	115	$	44	$	231	$	108

5. Segment Information

We have two 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 States; 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.”)

8Segment 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, 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.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

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, 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, 2024
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,551	$	115	$	—		$	1,666
Net gain on commodity derivatives	—		—		1		(b)	1
Income from equity method investments	—		26		—			26
Net gain on disposal of assets	—		—		10		(c)	10
Other income	1		2		1			4
Less costs and expenses:
Production	198		18		—			216
Shipping, handling and other operating, including related party	155		13		7			175
Exploration	10		—		4			14
Depreciation, depletion and amortization	562		10		5			577

Taxes other than income	103		—		—			103
General and administrative	41		4		54		(d)	99
Net interest and other	—		—		80			80
Other net periodic benefit credits	—		—		(2)			(2)

Income tax provision (benefit)	104		19		(27)			96
Segment income (loss)	$	379	$	79	$	(109)		$	349
Total assets	$	18,766	$	849	$	125		$	19,740
Capital expenditures(a)	$	660	$	3	$	2		$	665

	Three Months Ended March 31, 2024
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,422	$	116	$	—		$	1,538
Net loss on commodity derivatives	—		—		(24)		(b)	(24)
Income from equity method investments	—		39		—			39
Other income (expense)	(4)		1		1			(2)
Less costs and expenses:
Production	201		20		—			221
Shipping, handling and other operating, including related party	149		17		3			169
Exploration	7		—		—			7
Depreciation, depletion and amortization	500		10		14			524
Taxes other than income	96		—		—			96
General and administrative	38		3		45			86
Net interest and other	—		—		69			69
Other net periodic benefit costs	—		—		(3)			(3)
Income tax provision (benefit)	93		24		(32)			85
Segment income (loss)	$	334	$	82	$	(119)		$	297
Total assets	$	18,629	$	918	$	121		$	19,668
Capital expenditures(a)	$	598	$	1	$	4		$	603

(a)Includes accruals and excludes acquisitions.

(b)Unrealized gain on commodity derivative instruments (See Note 8).

(c)Pertains to a gain from the sale of a legacy royalty interest in the state of California.

(d)Includes $10 million of transaction costs associated with the Merger with ConocoPhillips (See Note 1).

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	Three Months Ended June 30, 2023
(In millions)	U.S.			Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,440		$	44	$	—		$	1,484
Net gain (loss) on commodity derivatives	7			—		(4)		(c)	3
Income from equity method investments	—			22		—			22

Other income	1			3		—			4
Less costs and expenses:
Production	191			23		—			214
Shipping, handling and other operating, including related party	161			—		—			161
Exploration	6			—		5			11
Depreciation, depletion and amortization	547			10		2			559

Taxes other than income	43		(b)	—		—			43
General and administrative	31			3		37			71
Net interest and other	—			—		92			92
Other net periodic benefit credits	—			—		(3)			(3)

Income tax provision (benefit)	104			3		(29)			78
Segment income (loss)	$	365		$	30	$	(108)		$	287
Total assets	$	18,761		$	1,006	$	152		$	19,919
Capital expenditures(a)	$	620		$	—	$	3		$	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 8).

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	Six Months Ended June 30, 2024
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	2,973	$	231	$	—		$	3,204
Net loss on commodity derivatives	—		—		(23)		(b)	(23)
Income from equity method investments	—		65		—			65
Net gain on disposal of assets	—		—		10		(c)	10
Other income (expense)	(3)		3		2			2
Less costs and expenses:
Production	399		38		—			437
Shipping, handling and other operating, including related party	304		30		10			344
Exploration	17		—		4			21
Depreciation, depletion and amortization	1,062		20		19			1,101

Taxes other than income	199		—		—			199
General and administrative	79		7		99		(d)	185
Net interest and other	—		—		149			149
Other net periodic benefit credits	—		—		(5)			(5)

Income tax provision (benefit)	197		43		(59)			181
Segment income (loss)	$	713	$	161	$	(228)		$	646
Total assets	$	18,766	$	849	$	125		$	19,740
Capital expenditures(a)	$	1,258	$	4	$	6		$	1,268

(a)Includes accruals and excludes acquisitions.

(b)Unrealized loss on commodity derivative instruments (See Note 8).

9(c)Pertains to a gain from the sale of a legacy royalty interest in the state of California.

(d)Includes $10 million of transaction costs associated with the Merger with ConocoPhillips (See Note 1).

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

	Three Months Ended March 31, 2023
	Six Months Ended June 30, 2023
(In millions)	U.S.			Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,503		$	64	$	—		$	1,567
Revenue from contracts with customers	$	2,943		$	108	$	—		$	3,051
Net gain on commodity derivatives	13			—		2		(b)	15
Net gain (loss) on commodity derivatives	20			—		(2)		(c)	18
Income from equity method investments	—			80102		—			80102
Net gain on disposal of assets	—			—		5			5
Other income	1112			14		1			1317
Less costs and expenses:
Production	~~178~~369			2346		—			~~201~~415
Shipping, handling and other operating, including related party	~~159~~320			3		—			~~162~~323
Exploration	511			—		1015		(cd)	1526
Depreciation, depletion and amortization	~~505~~1,052			1222		35			~~520~~1,079
Taxes other than income	97140		(b)	—		(2)			95138
General and administrative	3566			36		4481			82153
Net interest and other	—			—		82174			82174
Other net periodic benefit costs	—			—		(3)			(3)
Other net periodic benefit credits	—			—		(6)			(6)
Income tax provision (benefit)	~~123~~227			1518		(2958)			~~109~~187
Segment income (loss)	$	~~425~~790		$	89119	$	(97205)		$	~~417~~704
Total assets	$	18,~~696~~761		$	1,~~148~~006	$	~~168~~152		$	2019,~~012~~919
Capital expenditures(a)	$	~~597~~1,217		$	2	$	25		$	~~601~~1,224

(a)Includes accruals and excludes acquisitions.

(b)~~Unrealized~~Includes ~~gain~~a onnonrecurring ~~commodity~~Eagle ~~derivative~~Ford ~~instruments~~severance ~~(See~~tax ~~Note~~refund 8)of $47 million related to prior years.

(c)~~Includes~~Unrealized ~~$10 million~~loss ofon ~~dry~~commodity ~~well~~derivative ~~expense~~instruments ~~associated~~(See ~~with~~Note ~~wells in Permian~~8).

(d)Includes $10 million of dry well expense associated with wells in Permian.

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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 ~~March~~June 3130, 2024 and 2023, our effective income tax rates were as follows:

	Three Months Ended March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Effective income tax rate	22	%	21	%	22	%	21	%

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 are subject to the corporate book minimum tax in 2024. The U.S. Department of the Treasury and the IRS are expected to release further regulations and interpretive guidance implementing the legislation contained in the IRA. 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.

7. 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. During the fourth quarter of 2023, we repaid $300 million of outstanding borrowings. On March 28, 2024, we fully repaid the $1.2 billion outstanding balance under our Term Loan Facility by utilizing the net proceeds received from the senior notes issued during the first quarter of 2024 plus cash on hand (see Debt Issuance below).

Revolving Credit Facility and Commercial Paper Program

We have an unsecured revolving credit facility (“Revolving Credit Facility”) with a borrowing capacity of $2.6 billion. We have the option to increase the commitment amount by up to an additional $939 million, subject to the consent of any increasing lenders. The Revolving Credit Facility matures on July 28, 2027. At ~~March~~June 3130, 2024, we had anno ~~immaterial~~ outstanding ~~balance~~borrowings under our Revolving Credit Facility.

The Revolving Credit Facility includes a covenant requiring our total debt to total capitalization ratio, as defined in the credit agreement, 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 ~~March~~June 3130, 2024, we were in compliance with this covenant ~~with a ratio of 25%~~.

Commercial Paper Program

Pursuant to our 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 commercial paper program is backed by our $2.6 billion Revolving Credit Facility.

We utilize our commercial paper program to fund various short-term working capital requirements. As of ~~March~~June 3130, 2024, we had $~~450~~325 million of outstanding commercial paper maturing at various dates with a weighted average interest rate of 5.9087%.

11Under the Merger Agreement, we are permitted to borrow under our commercial paper program or Revolving Credit Facility, an aggregate amount not to exceed $1.5 billion outstanding.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

Debt issuance

On March 28, 2024, we completed a public offering of $1.2 billion aggregate principal amount of unsecured senior notes consisting of $600 million aggregate principal amount of 5.30% senior notes due April 1, 2029 (“2029 Notes”) and $600 million aggregate principal amount of 5.70% senior notes due April 1, 2034 (“2034 Notes”). Interest on the senior notes is payable semi-annually beginning October 1, 2024. We may redeem some or all of the senior notes at any time at the applicable redemption price, plus accrued interest, if any. Net proceeds received totaled approximately $1.2 billion. Debt issuance costs of $12 million were recorded as deferred financing costs within long-term debt in our consolidated balance sheets and are being amortized to interest expense in our consolidated statement of income over the term of each note. The net proceeds, together with cash on hand, were used to repay $1.2 billion of outstanding borrowings under our Term Loan Facility.

Debt redemption

In March 2023, we redeemed the $70 million 8.5% Senior Notes in connection with their maturity date.

Long-term debt

At ~~March~~June 3130, 2024, we had $5.0 billion of total long-term debt outstanding. Long-term debt due within one year consists of $200 million 2.10% of sub-series 2017A-2 bonds and $200 million 2.125% of sub-series 2017B-1 bonds, both of which feature a mandatory put on July 1, 2024. ~~Refer~~(see toDebt ~~our~~Remarketing ~~2023 Annual Report on Form 10-K for a listing of our long-term debt maturities~~below).

Refer to our 2023 Annual Report on Form 10-K for a listing of our long-term debt maturities. Under the Merger Agreement, we are subject to restrictions and limitations that prevent us from incurring additional debt, or redeeming all or a portion of our existing outstanding debt, except permitted borrowings under our commercial paper program or Revolving Credit Facility (see Revolving Credit Facility and Commercial Paper Program above).

Debt Remarketing

In April 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.

As a subsequent event, on July 1, 2024, using short-term borrowings, we purchased $200 million of our outstanding sub-series 2017 A-2 bonds and $200 million of our outstanding sub-series 2017 B-1 bonds that are part of the $1.0 billion Parish of St. John The Baptist, State of Louisiana Revenue Refunding Bonds (Marathon Oil Corporation Project) Series 2017. The $400 million of bonds due 2037 were purchased on their mandatory put date of July 1, 2024, for our own account and are subject to an interest rate of 4.125%. We have the right, subject to the consent of ConocoPhillips, to convert and remarket these bonds to the public at any time up to their June 1, 2037 maturity date.

8. 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 9. 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. Under the Merger Agreement, we are subject to limitations on our ability to enter into new derivative transactions.

~~The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with their locations in our consolidated balance sheets:~~ 16

	March 31, 2024
(In millions)	Asset		Liability		Net Asset		Balance Sheet Location
Not Designated as Hedges
Commodity	$	1	$	1	$	—	Other current assets
Total Not Designated as Hedges	$	1	$	1	$	—
Cash Flow Hedges
Interest Rate	$	9	$	—	$	9	Other current assets
Interest Rate	10		—		10		Other noncurrent assets
Total Designated Hedges	$	19	$	—	$	19
Total	$	20	$	1	$	19

	December 31, 2023
(In millions)	Asset		Liability		Net Asset		Balance Sheet Location
Not Designated as Hedges
Commodity	$	24	$	—	$	24	Other current assets
Total Not Designated as Hedges	$	24	$	—	$	24
Cash Flow Hedges
Interest Rate	$	9	$	—	$	9	Other current assets
Interest Rate	9		—		9		Other noncurrent assets
Total Designated Hedges	$	18	$	—	$	18
Total	$	42	$	—	$	42

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with their locations in our consolidated balance sheets:


	June 30, 2024
(In millions)	Asset		Liability		Net Asset		Balance Sheet Location
Not Designated as Hedges
Commodity	$	1	$	—	$	1	Other current assets




Total Not Designated as Hedges	$	1	$	—	$	1

Cash Flow Hedges
Interest Rate	$	9	$	—	$	9	Other current assets
Interest Rate	9		—		9		Other noncurrent assets


Total Designated Hedges	$	18	$	—	$	18
Total	$	19	$	—	$	19


	December 31, 2023
(In millions)	Asset		Liability		Net Asset		Balance Sheet Location
Not Designated as Hedges
Commodity	$	24	$	—	$	24	Other current assets


Total Not Designated as Hedges	$	24	$	—	$	24

Cash Flow Hedges
Interest Rate	$	9	$	—	$	9	Other current assets
Interest Rate	9		—		9		Other noncurrent assets
Total Designated Hedges	$	18	$	—	$	18
Total	$	42	$	—	$	42

Derivatives Not Designated as Hedges

Commodity Derivatives

We have entered into crude oil and natural gas derivatives indexed to their respective indices as noted in the table below, related to a portion of our forecasted U.S. sales through ~~2024~~2025. These derivatives are three-way collars and two-way 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 plus the difference between the floor and the sold put price. Two-way collars only consists of a sold call (ceiling) and a purchased put (floor). These crude oil and natural gas derivatives were not designated as hedges.

~~The following table sets forth outstanding derivative contracts as of March 31, 2024, and the weighted average prices for those contracts:~~17

	2024
		Second Quarter		Third Quarter		Fourth Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)		60,000		40,000		40,000
Weighted average price per Bbl:
Ceiling		$	97.44	$	96.12	$	96.12
Floor		$	65.83	$	65.00	$	65.00
Sold put		$	50.83	$	50.00	$	50.00

The following table sets forth outstanding derivative contracts as of April 30, 2024, with their weighted average prices, and is inclusive of activities that occurred subsequent to March 31, 2024:

	2024	2025
		Second Quarter		Third Quarter		Fourth Quarter		First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)		60,000		50,000		50,000		—		—		—		—
Weighted average price per Bbl:
Ceiling		$	97.44	$	95.95	$	95.95	$	—	$	—	$	—	$	—
Floor		$	65.83	$	65.00	$	65.00	$	—	$	—	$	—	$	—
Sold put		$	50.83	$	50.00	$	50.00	$	—	$	—	$	—	$	—
Natural Gas
Henry Hub Two-Way Collars
Volume (MMBtu/day)		—		—		—		100,000		100,000		100,000		100,000
Weighted average price per MMBtu:
Ceiling		$	—	$	—	$	—	$	5.77	$	5.77	$	5.77	$	5.77
Floor		$	—	$	—	$	—	$	2.50	$	2.50	$	2.50	$	2.50

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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, 2024, and the weighted average prices for those contracts:


	2024					2025
		Third Quarter		Fourth Quarter			First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)		50,000		50,000			—		—		—		—
Weighted average price per Bbl:
Ceiling		$	95.95	$	95.95		$	—	$	—	$	—	$	—
Floor		$	65.00	$	65.00		$	—	$	—	$	—	$	—
Sold put		$	50.00	$	50.00		$	—	$	—	$	—	$	—





















Natural Gas
Henry Hub Two-Way Collars
Volume (MMBtu/day)		—		—			150,000		150,000		150,000		150,000
Weighted average price per MMBtu:
Ceiling		$	—	$	—		$	5.85	$	5.85	$	5.85	$	5.85
Floor		$	—	$	—		$	2.50	$	2.50	$	2.50	$	2.50

The unrealized gain (loss) and realized gain 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 March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2024		2023		2024		2023
Unrealized gain (loss) on derivative instruments, net	$	~~(24)~~1	$	2(4)	$	(23)	$	(2)
Realized gain on derivative instruments, net(a)	$	—	$	137	$	—	$	20

(a)During the ~~first~~second quarter and first six months of 2024, we had no settled derivative positions. During the ~~first~~second quarter and first six months of 2023, net cash received for settled derivative positions was $107 million and $17 million, respectively.

Derivatives Designated as Cash Flow Hedges

During 2019, we entered into forward starting interest rate swaps with a maturity date of September 9, 2026 to hedge variations in cash flows related to the interest rate component of future lease payments of our Houston office. As of ~~March~~June 3130, 2024 and December 31, 2023, the notional amount of open interest rate swaps for the Houston office was $295 million. The weighted average secured overnight financing rate (“SOFR”) for the swaps was 1.43% as of both ~~March~~June 3130, 2024 and December 31, 2023.

During the ~~three~~six months ended ~~March~~June 3130, 2024, net cash received for the settled interest rate swap positions was $36 million. As of ~~March~~June 3130, 2024, we expect to reclassify a $10 million gain from accumulated other comprehensive income into our consolidated statements of income over the next twelve months.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

9. Fair Value Measurements

Fair Values – Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of ~~March~~June 3130, 2024 and December 31, 2023 by hierarchy level:

	March 31, 2024
	June 30, 2024
(In millions)	Level 1		Level 2		Level 3		Total
Derivative instruments, assets
Commodity(a)	$	—	$	1	$	—	$	1
Interest rate - designated as cash flow hedges	—		1918		—		1918
Derivative instruments, assets	$	—	$	2019	$	—	$	2019
Derivative instruments, liabilities
Commodity(a)	$	—	$	(1)	$	—	$	(1)
Derivative instruments, liabilities	$	—	$	(1)	$	—	$	(1)
Total	$	—	$	19	$	—	$	19


	December 31, 2023
(In millions)	Level 1		Level 2		Level 3		Total
Derivative instruments, assets
Commodity(a)	$	—	$	24	$	—	$	24
Interest rate - designated as cash flow hedges	—		18		—		18
Derivative instruments, assets	$	—	$	42	$	—	$	42

(a)Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 8.

14As of June 30, 2024, our commodity derivatives include three-way collars and two-way collars. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. For three-way collars and two-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.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

As of March 31, 2024, our commodity derivatives include three-way collars. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. 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 8 for details on the forward starting interest rate swaps.

Fair Values – Financial Instruments

Our current assets and liabilities include financial instruments, the most significant of which are receivables, commercial paper borrowings, the current portion of our long-term debt and payables. We believe the carrying values of our receivables, commercial paper borrowings 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.

The following table summarizes financial instruments, excluding receivables, commercial paper borrowings, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at March 31, 2024 and December 31, 2023:19

	March 31, 2024				December 31, 2023
(In millions)	Fair Value		Carrying Amount		Fair Value		Carrying Amount
Financial assets
Other noncurrent assets	$	9	$	29	$	9	$	27
Total financial assets	$	9	$	29	$	9	$	27
Financial liabilities
Other current liabilities	$	80	$	127	$	80	$	126
Long-term debt, including current portion(a)	4,987		5,003		4,961		4,997
Deferred credits and other liabilities	70		72		70		71
Total financial liabilities	$	5,137	$	5,202	$	5,111	$	5,194

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	June 30, 2024				December 31, 2023
(In millions)	Fair Value		Carrying Amount		Fair Value		Carrying Amount
Financial assets

Other noncurrent assets	$	10	$	30	$	9	$	27
Total financial assets	$	10	$	30	$	9	$	27
Financial liabilities
Other current liabilities	$	80	$	126	$	80	$	126
Long-term debt, including current portion(a)	5,050		4,996		4,961		4,997
Deferred credits and other liabilities	71		73		70		71
Total financial liabilities	$	5,201	$	5,195	$	5,111	$	5,194

(a)Excludes debt issuance costs.

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.

Our fixed rate debt instruments are publicly traded. The 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. Our floating rate debt is non-public and consists of borrowings under our Revolving Credit Facility. The fair value of our floating rate debt approximates the carrying value and is estimated based on observable market-based inputs, which results in a Level 2 classification.

10. Property, Plant and Equipment

(In millions)	~~March~~June 3130, 2024		December 31, 2023
United States	$	17,~~004~~097	$	16,905
International	~~243~~235		252
Corporate	5655		56
Net property, plant and equipment	$	17,~~303~~387	$	17,213

As of ~~March~~June 3130, 2024 and December 31, 2023, we had no exploratory well costs capitalized greater than one year related to suspended wells.

1520

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

11. 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:

	March 31,
	June 30,
(In millions)	2024		2023
Beginning balance as of January 1	$	340	$	340
Incurred liabilities, including acquisitions	25		13
Settled liabilities, including dispositions	(27)		(920)
Accretion expense (included in depreciation, depletion and amortization)	48		47
Revisions of estimates	2		59
Ending balance as of March 31, total	$	346	$	341
Ending balance as of June 30, total	$	348	$	339
Ending balance as of March 31, short-term	$	17	$	45
Ending balance as of June 30, short-term	$	12	$	40

12. Equity Method Investments

During the periods ended ~~March~~June 3130, 2024 and December 31, 2023, our equity method investees were considered related parties. Our ~~investment~~investments in our equity method investees are summarized in the following table:

(In millions)	Ownership as of ~~March~~June 3130, 2024	~~March~~June 3130, 2024		December 31, 2023
EG LNG (a)	56%	$	~~132~~104	$	118
Alba Plant LLC (b)	52%	~~176~~151		153
AMPCO (c)	45%	~~164~~166		162
Total		$	~~472~~421	$	433

(a)EG LNG 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 March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2024		2023		2024		2023
Income data:
Revenues and other income	$	~~211~~183	$	~~306~~183	$	394	$	489
Income from operations	~~101~~58		~~159~~43		159		202
Net income	$	8446	$	~~134~~30	$	130	$	164

Revenues from related parties were $23 million and $5 million for the three and six months ended ~~March~~June 3130, 2024, respectively, which primarily related to Alba Plant LLC and AMPCO. Revenues from related parties were $65 million and $11 million for the three and six months ended ~~March~~June 3130, 2023, respectively, with the majority related to EG LNG. As a result of the agreement that took effect on January 1, 2024, related party shipping, handling and other operating expense presented on the face of the consolidated statements of income represents compensation to EG LNG for liquefaction, storage and product handling services.

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. Our equity investees did not distribute dividends or return of capital during the three months ended March 31, 2024 and 2023.21

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

~~Current~~Cash ~~receivables~~received from ~~related~~equity ~~parties~~investees ~~were~~is ~~$23~~classified ~~million~~as ~~and~~dividends ~~$24 million~~or atreturn ~~March 31,~~of ~~2024~~capital ~~and~~on ~~December 31,~~the ~~2023,~~Consolidated ~~respectively,~~Statements ~~which~~of ~~primarily~~Cash ~~related~~Flows. toDividends EGfrom ~~LNG~~equity ~~and~~method ~~Alba~~investees ~~Plant~~are ~~LLC~~reflected in ~~both~~the ~~periods~~Operating activities section in Equity Method Investments, net while return of capital is reflected in the Investing activities section. ~~Payables~~Dividends toand ~~related~~return ~~parties~~of ~~were~~capital ~~$24~~received by us totaled $77 million during the three and $6six ~~million~~months atended ~~March~~June 3130, 2024 and ~~December~~$249 ~~31,~~million ~~2023,~~during ~~respectively, with~~ the ~~majority~~three ~~related~~and tosix EGmonths ~~LNG~~ended inJune 30, ~~both periods~~2023.

Current receivables from related parties were $36 million and $24 million at June 30, 2024 and December 31, 2023, respectively, which primarily related to EG LNG and Alba Plant LLC in both periods. Payables to related parties were $25 million and $6 million at June 30, 2024 and December 31, 2023, respectively, with the majority related to EG LNG in both periods.

Related Party Lease Transaction

Our wholly owned subsidiary, MEGPL, is a lessor for residential housing in E.G., which is occupied by EG LNG. The lease was classified as an operating lease ~~and~~with ~~expires~~an initial term expiring in 2024. On June 30, ~~with~~2024, athe lessee exercised an option to extend the lease 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)	Operating Lease Future Cash Receipts
2024	$	54
2025	6
2026	6
2027	6
2028	6
Thereafter	35
Total undiscounted cash flows	$	6463

13. Stockholders’ Equity

Our Board of Directors has authorized a share repurchase program. During the first ~~three~~six months of 2024, we repurchased 11approximately 19 million shares of our common stock pursuant to the share repurchase program at a cost of $~~285~~516 million. Our remaining share repurchase authorization was approximately $21.08 billion at ~~March~~June 3130, 2024. Purchases under our repurchase 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.

~~Subsequent~~Upon tothe announcement of the ~~quarter~~Merger Agreement, we ~~repurchased~~suspended ~~approximately~~our ~~$110 million~~stock ofrepurchase ~~shares~~activity ofas ~~our~~we ~~common~~are ~~stock~~subject ~~through~~to ~~May~~certain 1restrictions to our ability to repurchase, ~~2024~~redeem or otherwise acquire our capital stock.

1722

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

14. Incentive Based Compensation

Stock options and restricted stock units

The following table presents a summary of activity for the first ~~three~~six months of 2024:

	Stock Options			Restricted Stock Units
	Number of Shares	Weighted Average Exercise Price		Number of Shares & Units	Weighted Average Grant Date Fair Value
Outstanding at December 31, 2023	1,004,304	$	31.38	3,514,405	$	22.07
Granted	—	—		2,062,612	24.60
Exercised/Vested	—(13,889)	—10.47		(1,663,913)	19.18
Canceled	(~~499~~649,~~545~~764)	33.3378		(45133,~~300~~856)	2324.0010
Outstanding at March 31, 2024	504,759	$	29.44	3,867,804	$	24.65
Outstanding at June 30, 2024	340,651	$	27.64	3,779,248	$	24.65

In accordance with the Merger Agreement, each outstanding and vested Marathon Oil option award granted pursuant to the Marathon Oil stock plan will be canceled and converted into the right to receive a number of shares of ConocoPhillips common stock (rounded down to the nearest whole share) equal to the quotient of (i) the product of (A) the excess, if any, of the Merger Consideration Value (as defined below) over the per share exercise price, multiplied by (B) the number of shares of Marathon Oil common stock subject to such Marathon Oil option award immediately prior to the Effective Time, divided by (ii) the volume-weighted average price of the ConocoPhillips common stock for the five consecutive trading days ending two trading days prior to the closing date (the “Parent Closing Price”). Any Marathon Oil option award that has an exercise price per share that is equal to or greater than the Merger Consideration Value will be canceled for no consideration. The term “Merger Consideration Value” means the product of (x) the Exchange Ratio multiplied by (y) the Parent Closing Price.

At closing, restricted stock units will be canceled and converted into an award of ConocoPhillips common stock at the Exchange Ratio and will be subject to the same vesting conditions that existed prior to the closing of the Merger Agreement. Any restricted stock units held by non-employee directors of Marathon Oil will fully vest at closing and be converted, at the Exchange Ratio, into the right to receive ConocoPhillips common stock. Additionally, consummation of the Merger constitutes a change in control as defined under our 2019 Incentive Compensation Plan. After a change in control has occurred, restricted stock units granted to employees who are involuntarily separated, under certain conditions, will immediately vest as ConocoPhillips common stock.

Stock-based performance unit awards

During the first ~~three~~six months of 2024, we granted 248,572 stock-based performance units to eligible officers, which are settled in shares. The grant date fair value per unit was $28.21. During the first ~~three~~six months of 2024, we stock settled the units related to the 2021 grant. At ~~March~~June 3130, 2024, there were 638,079 outstanding stock-based performance units to be settled in shares to officers.

During the first ~~three~~six months of 2024, we also granted 248,572 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 one share of our common stock. The fair value of each cash-settled performance unit was $28.4589 as of ~~March~~June 3130, 2024. During the first ~~three~~six months of 2024, we also cash settled the units related to the 2022 grant. At ~~March~~June 3130, 2024, there were 471,036 units outstanding of the stock-based performance unit awards to be settled in cash to officers.

In accordance with the Merger Agreement, each stock-based performance unit that is outstanding immediately prior to closing will vest. Outstanding performance units were initially granted assuming a target payout; however, at closing, all outstanding performance units will vest at the maximum payout percentage of 200% of target.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

15. Inventories

Crude oil, NGLs and natural gas, including LNG, 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)	~~March~~June 3130, 2024		December 31, 2023
Crude oil, NGLs and natural gas, including LNG	$	1210	$	14
Supplies and other items	~~167~~151		172
Inventories	$	~~179~~161	$	186

16. Supplemental Cash Flow Information

	Three Months Ended March 31,
	Six Months Ended June 30,
(In millions)	2024		2023
Included in operating activities:
Interest paid	$	73127	$	85139
Income taxes paid, net of refunds	$	859	$	697
Noncash investing activities:
Increase in asset retirement costs	$	47	$	612

Other noncash investing activities include accrued capital expenditures for the ~~three~~six months ended ~~March~~June 3130, 2024 and 2023 of $~~203~~222 million and $~~180~~169 million, respectively.

1817. Commitments and Contingencies

Various groups, including the State of North Dakota and the Mandan, Hidatsa and Arikara Nation or MHA Nation, also known as the Three Affiliated Tribes of the Fort Berthold Indian Reservation (the “Three Affiliated Tribes”) represented by the Bureau of Indian Affairs (the “BIA”), 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, 2024, we have a $123 million current liability in suspended royalty and working interest revenue, including interest, of which $104 million was included within accounts payable and $19 million related to accrued interest was included within other current liabilities on our consolidated balance sheet. Additionally, we have a long-term receivable of $29 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 in recent years with conflicting opinions. In January 2017, the DOI issued an opinion that the Disputed Land is held in trust for the Three 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 that the Disputed Land is held in trust for the Three Affiliated Tribes. While the M-Opinion is binding on all agencies within the DOI, it is not legally binding on third parties, including Marathon Oil, the State of North Dakota, or a court. 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.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

17We received Notices of Violation (“NOVs”) from the EPA related to alleged violations of the Clean Air Act with respect to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. ~~Commitments~~ On July 10, 2024, we entered into a consent decree with the EPA and ~~Contingencies~~Department of Justice to fully resolve this matter. The consent decree is subject to a 30-day public comment period before it may be considered for entry by the court. The consent decree will require the completion of mitigation projects, implementation of specific injunctive relief and payment of a $65 million civil penalty with substantially all of that civil penalty accrued in our previously filed quarterly report for the period ending March 31, 2024. In 2022, we began early implementation of the injunctive requirements associated with likely settlement terms and are scheduled to complete this work in 2025. The total cost associated with the injunctive relief is estimated to be approximately $177 million, but over 70% of that cost has been incurred or included in the previously announced 2024 capital budget with the remaining amount to be spent by the end of 2025. The consent decree sets forth a detailed compliance schedule with deadlines for achievement of milestones through at least 2026. The consent decree further contains requirements for ongoing permitting, inspection and monitoring, maintenance, auditing, and reporting. Findings from such inspection, monitoring and auditing activities may result in decisions to temporarily shut in or reduce production from certain wells and facilities.

~~Various~~We groups, including the State of North Dakota and the Mandan, Hidatsa and Arikara Nation or MHA Nation, also known as the Three Affiliated Tribes of the Fort Berthold Indian Reservation (the “Three Affiliated Tribes”) represented by the Bureau of Indian Affairs (the “BIA”), have ~~been~~cooperated ~~involved~~fully inwith ~~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~~EPA, ~~as of March 31, 2024, we have a $123 million current liability in suspended royalty and working interest revenue,~~ including ~~interest,~~collecting ~~of which $105 million was included within accounts payable~~ and ~~$18 million~~sharing ~~related~~extensive data to ~~accrued~~resolve ~~interest~~this ~~was included within other current liabilities on our consolidated balance sheet~~matter. ~~Additionally, we have a long-term receivable of $27 million for capital and expenses.~~ The ~~United~~vast ~~States~~majority ~~Department~~ of ~~the~~emission ~~Interior~~reductions ~~(“DOI”)~~are ~~has~~being ~~addressed~~achieved ~~the~~by ~~United States~~Marathon’s ~~position~~voluntary ~~with~~commitment ~~respect~~ to ~~this~~incorporate ~~dispute~~industry-leading ~~several times in recent years with conflicting opinions. In January 2017~~technologies, ~~the~~like ~~DOI~~our ~~issued~~new anlowest ~~opinion~~emitting ~~that~~automated ~~the~~facilities Disputed Land is held in trust for the Three 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”~~LEAF) ~~concluding that the Disputed Land is held in trust for the Three Affiliated Tribes~~. ~~While~~We ~~the~~do ~~M-Opinion is binding on all agencies within the DOI, it is~~ not ~~legally~~admit ~~binding~~liability onregarding ~~third~~any ~~parties, including Marathon Oil, the State~~ of ~~North Dakota, or a court. Given~~ the ~~uncertainty~~allegations in ~~matters~~the ~~such~~complaint asassociated ~~these,~~with ~~we are unable to predict~~ the ~~ultimate~~consent ~~outcome~~decree ofand ~~this~~elected ~~matter~~to atresolve ~~this time; however, we believe~~ the ~~resolution~~allegations ofin ~~this matter will not have~~ a ~~material~~negotiated ~~adverse~~settlement ~~effect~~rather onthan ~~our consolidated financial position, results of operations or cash flows~~litigation.

We ~~are~~have areceived ~~defendant~~NOVs infrom athe ~~number~~EPA ofrelating ~~legal~~to ~~and~~alleged ~~administrative~~Clean ~~proceedings~~Air ~~arising~~Act inviolations ~~the~~following ~~ordinary~~flyovers ~~course~~conducted ofin ~~business~~2020 ~~including,~~and ~~but~~2022 ~~not~~over ~~limited~~certain ~~to,~~of ~~royalty~~our ~~claims,~~oil ~~contract~~and ~~claims,~~gas ~~tax~~facilities ~~disputes~~in ~~and~~New ~~environmental claims~~Mexico. ~~While~~ ~~the~~The ~~ultimate~~notices ~~outcome~~involve ~~and~~alleged ~~impact~~emission toand uspermitting ~~cannot~~violations. beAs ~~predicted~~previously ~~with certainty~~disclosed, we ~~believe the resolution of these proceedings will not~~ have abeen ~~material~~in ~~adverse~~discussions ~~effect~~with onthe ~~our~~EPA ~~consolidated~~to ~~financial~~resolve ~~position,~~these ~~results of operations or cash flows~~matters. In ~~addition,~~order ~~we may also be subject~~ to ~~retained~~fully ~~liabilities~~resolve ~~with~~these ~~respect~~matters, toeffective ~~certain~~July ~~divested~~25, ~~assets by operation of law. For example~~2024, we ~~are~~entered ~~exposed~~into toa ~~the~~consent ~~risk~~agreement ~~that~~with ~~owners~~the ~~and/or~~EPA ~~operators~~pursuant ~~of assets purchased from us become unable~~ to ~~satisfy~~which ~~plugging~~we oragreed ~~abandonment obligations that attach~~ to ~~those~~pay ~~assets.~~a Incivil ~~that~~penalty ~~event,~~in ~~due~~the toamount ~~operation~~ of ~~law~~$265,000. weWe ~~may~~do benot ~~required~~believe tothat ~~assume~~any ~~plugging~~penalty or ~~abandonment~~corrective ~~obligations~~action ~~for~~expenditures ~~those~~that ~~assets.~~may ~~Although~~result wefrom ~~have~~this ~~established~~matter ~~reserves~~will ~~for~~have ~~such~~a ~~liabilities,~~material weadverse ~~could~~effect beon ~~required~~our tofinancial ~~accrue~~position, ~~additional~~results ~~amounts~~of inoperation ~~the~~or ~~future~~cash ~~and these amounts could be material~~flows.

We have received Notices of Violation (“NOVs”) from the EPA related to alleged violations of the Clean Air 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. The resolution of the enforcement action will likely include monetary sanctions, for which we maintain an updated accrual as matters progress, and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. There remains uncertainty as to the ultimate result of this matter and it is possible the result could be materially different from our expectations and our accrual.

We have received NOVs from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 and 2022 over certain of our 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. At this time, we are unable to estimate the potential loss associated with these matters, however, it is reasonably possible that resolution of these matters may result in a fine or penalty in excess of $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.

At ~~March~~June 3130, 2024, 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 costs that might be incurred or the penalties that may be imposed.

19In 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.

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MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

InThe agreements to process the ~~second~~third-party ~~quarter~~Alen Unit gas required the execution of ~~2019,~~third-party guarantees by Marathon EOil in favor of the Alen Unit’s owners.G. Two ~~Production~~separate ~~Limited~~guarantees ~~(“MEGPL”),~~were aexecuted ~~consolidated~~during ~~and~~the ~~wholly~~second ~~owned~~quarter ~~subsidiary,~~of ~~signed~~2020; one for a ~~series~~maximum of ~~agreements~~approximately to$91 ~~process~~million ~~third-party~~pertaining ~~Alen~~to ~~Unit~~the ~~gas~~payment ~~through~~obligations ~~existing~~of ~~infrastructure~~Equatorial ~~located~~Guinea inLNG ~~Punta Europa~~Operations, ES.GA. ~~Our~~and ~~equity~~another ~~method~~for ~~investee,~~a ~~Alba~~maximum ~~Plant~~of ~~LLC,~~$25 ismillion ~~also~~pertaining ato ~~party~~the topayment ~~some~~obligations of ~~the~~Alba ~~agreements~~Plant LLC. ~~These~~Payment ~~agreements~~by ~~require~~us ~~(subject~~would be required if any of those entities fails to ~~certain~~honor ~~limitations)~~its ~~MEGPL~~payment obligations pursuant to ~~indemnify~~the relevant agreements with the owners of the Alen Unit. Certain ~~against~~owners ~~injury~~of tothe ~~Alba~~Alen ~~Plant~~Unit, ~~LLC’s~~or ~~personnel~~their ~~and~~affiliates, ~~damage~~are toalso direct or ~~loss~~indirect ofshareholders ~~Alba~~in ~~Plant~~Equatorial ~~LLC’s~~Guinea ~~automobiles~~LNG Operations, asS.A. ~~well~~and asAlba ~~third~~Plant ~~party~~LLC. Each ~~claims~~guarantee ~~caused~~expires byno ~~Alba~~later ~~Plant~~than ~~LLC~~December ~~and~~31, ~~certain~~2027. We ~~environmental~~measured ~~liabilities~~these ~~arising~~guarantees ~~from~~at ~~certain~~fair ~~hydrocarbons~~value inusing the ~~custody~~net ofpresent ~~Alba~~value ~~Plant~~of ~~LLC.~~premium Atpayments ~~this~~we ~~time,~~expect weto ~~cannot~~receive ~~reasonably~~from ~~estimate~~our ~~this~~investees. ~~obligation~~Our asliability wefor dothese ~~not~~guarantees ~~have~~was ~~any~~approximately ~~history~~$4 million as of ~~prior~~June 30, ~~indemnification~~2024. ~~claims~~Each orof ~~environmental~~Equatorial ~~discharge~~Guinea orLNG ~~contamination~~Operations, S.A. ~~Therefore,~~and weEquatorial ~~have~~Guinea ~~not~~LNG ~~recorded~~Train a1, ~~liability~~S.A. ~~with~~provided ~~respect~~us towith ~~these~~a ~~indemnities~~pledge ~~since~~of ~~the~~its ~~amount~~receivables ofas ~~potential~~recourse ~~future~~against any payments we may make under ~~these~~the ~~indemnification~~guaranty ~~clauses~~of isEquatorial ~~not~~Guinea ~~determinable~~LNG Operations, S.A.’s performance.

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 March 31, 2024. 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. 26

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Results of Operations

Critical Accounting Estimates

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, Permian in New Mexico and Texas and STACK and SCOOP in Oklahoma. Our U.S. assets are complemented by our international operations in E.G. As shown in our 2023 Annual Report on Form 10-K, our Vision and Mission are supported by our Foundation and Values. We expect to achieve our Vision by adherence to a capital allocation framework that limits our capital expenditures relative to our expected cash flow from operations. We allocate capital to prioritize shareholder returns and per share growth, exercise discipline in reinvestment, retire outstanding debt and replenish inventory.

~~Below~~Proposed ~~are certain key financial and operational highlights for the quarter:~~ Merger

~~Financial~~On May 28, 2024, we entered into the Merger Agreement with ConocoPhillips and ~~operational~~Merger ~~results~~Sub. The Merger Agreement provides that, among other things and subject to the terms and conditions of the Merger Agreement, Merger Sub will be merged with and into Marathon Oil, with Marathon Oil surviving and continuing as the surviving corporation in the Merger as a direct, wholly owned subsidiary of ConocoPhillips. Under the terms of the Merger Agreement, at the Effective Time, each of our outstanding shares of common stock (other than certain Excluded Shares and Converted Shares) will be converted to the right to receive the Merger Consideration. The Merger Agreement also contains certain customary termination rights of each of Marathon Oil and ConocoPhillips, and under certain circumstances, a termination fee would be payable by us. The Merger is expected to close late in the fourth quarter of 2024, subject to shareholder and regulatory approvals and other customary closing conditions; however, no assurance can be given as to when, or if, the Merger will occur.

~~•Our~~On ~~net~~July ~~income~~11, ~~was~~2024, ~~$297~~Marathon ~~million~~Oil and ConocoPhillips each received a request for additional information and documentary materials (together, the “Second Request”) from the Federal Trade Commission (the “FTC”) in connection with the ~~first~~FTC’s ~~quarter~~review of ~~2024~~the asMerger. ~~compared~~Issuance toof ~~net~~the ~~income~~Second Request extends the waiting period imposed by the Hart-Scott-Rodino Antitrust Improvements Act of ~~$417~~1976, ~~million~~as inamended until 30 days after Marathon Oil and ConocoPhillips have substantially complied with the ~~same~~Second Request, unless that period ~~last~~is ~~year~~terminated sooner by the FTC. ~~Included~~Marathon Oil and ConocoPhillips will continue to work cooperatively with the FTC in ~~our~~its ~~financial~~review ~~results~~of ~~for~~the Merger and continue to expect that the ~~current~~Merger will be completed in the fourth quarter: of 2024, subject to the fulfillment of the other closing conditions.

~~◦Revenue~~In ~~from~~association ~~contracts~~ with ~~customers~~the inMerger, ~~our~~we UShave ~~segment~~incurred ~~declined~~ $8110 million of transaction costs recorded as general and administrative expense in the ~~first~~consolidated ~~quarter~~statements of ~~2024~~income ~~compared~~for to the ~~same~~three ~~period~~and ofsix ~~2023.~~months ~~The~~ended ~~primary~~June ~~drivers~~30, of2024, and expect to incur additional costs as the ~~decrease~~Merger ~~were~~progresses. ~~lower~~Transaction ~~gas~~costs ~~and~~consist ~~NGL~~primarily ~~prices~~of ~~and~~third ~~slightly~~party ~~lower~~legal ~~sales~~and ~~volumes~~banking fees.

~~◦In~~If ~~our~~the ~~International~~Merger ~~segment~~is consummated, weMarathon ~~sold~~Oil’s ~~our~~common ~~initial~~stock ~~shipments~~will ofbe ~~LNG~~delisted ~~with~~from athe ~~global~~New ~~pricing~~York ~~linkage.~~Stock WeExchange ~~realized~~and ~~revenue~~deregistered ofunder ~~$51 million from LNG sales in~~ the ~~quarter~~Exchange Act, and ~~ended~~Marathon ~~the~~Oil ~~quarter~~will ~~with~~cease ato ~~positive~~be ~~LNG~~a ~~inventory~~publicly ~~balance~~traded ~~that was included in our April sales~~company. ~~Refer to Operations for additional information.~~

~~◦Provision~~Additionally, ~~for~~the ~~income~~Merger ~~taxes~~Agreement ~~decreased~~imposes ~~$24~~restrictions ~~million~~on ~~compared~~our tobusiness and operations during the ~~same~~pendency ~~quarter~~of ~~last~~the ~~year~~Merger. asWhile awe ~~result~~do not believe those restrictions are unduly burdensome, they may delay or prevent us from taking actions we could otherwise take. Accordingly, our results of ~~lower~~operations ~~income~~from before ~~taxes~~the Merger Agreement may not be comparable to results of operations since the we entered into the Merger Agreement. ~~Our~~See ~~tax~~Note ~~rate~~1 ~~was~~to ~~largely~~the ~~consistent~~consolidated infinancial ~~each~~statements ~~period~~for additional information on the Merger and Part II, Item 1A. Risk Factors for a discussion of risks related to the Merger.

~~Prioritized return of capital to investors and maintained investment grade balance sheet~~ 27

•In the first three months of 2024, we successfully issued $600 million 5.30% 2029 Notes and $600 million 5.70% 2034 Notes. Net proceeds totaled $1.2 billion and were used to repay the $1.2 billion outstanding balance under our Term Loan Facility.

•In the first three months of 2024, we repurchased $285 million of shares through our share repurchase program.

•As of March 31, 2024, we have $49 million of cash on hand and $2.2 billion of total liquidity.

•During the first three months of 2024, we paid $64 million of dividends, or $0.11 per share, compared to dividends paid of $0.10 per share during the first three months of 2023.

•All three primary credit rating agencies continue to rate us as investment grade.

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Financial and operational results

•Our net income was $349 million in the second quarter of 2024 as compared to net income of $287 million in the same period last year. Included in our financial results for the current quarter:

◦Revenue from contracts with customers in our US segment increased $111 million in the second quarter of 2024 compared to the same period of 2023. The primary drivers of the increase were higher crude and NGL prices, partially offset by a decrease in realized natural gas prices.

◦In our International segment we realized revenue of $84 million in the second quarter of 2024 from shipments of LNG with global pricing linkage that began in 2024. Refer to Op erations for additional information.

◦Received EG dividend distribution and return of capital totaling $77 million.

◦Provision for income taxes increased $18 million compared to the same quarter last year as a result of higher income before taxes. Our tax rate was largely consistent in each period.

Outlook

Capital Budget

In February 2024, we announced a 2024 capital budget of $1.9 billion to $2.1 billion. ~~that~~The ~~prioritizes~~midpoint ~~free~~of ~~cash~~our ~~flow~~oil ~~generation~~production ~~and~~guidance ~~meaningful~~for ~~return~~2024 ofis ~~capital~~190 tombopd. ~~shareholders~~As of June 30, ~~consistent~~2024, ~~with~~we ~~our~~are ~~disciplined~~reaffirming both our capital ~~allocation~~and ~~framework~~production guidance ranges for 2024. The ~~midpoint~~terms of ~~our~~the ~~oil~~Merger ~~production~~Agreement ~~guidance~~restrict ~~for~~us ~~2024~~from iscertain ~~190~~expansions ~~mbopd~~to our capital budget.

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 March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
Net Sales Volumes	2024	2023	Increase (Decrease)		2024	2023	Increase (Decrease)
United States (mboed)	~~326~~351	~~341~~356	(41)	%	339	349	(3)	%
International (mboed)	4342	5644	(235)	%	42	50	(16)	%
Total (mboed)	~~369~~393	~~397~~400	(72)	%	381	399	(5)	%

United States

The following tables provide additional details regarding net sales volumes, sales mix and operational drilling activity for our significant operations within this segment:

	Three Months Ended March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
Net Sales Volumes	2024	2023	Increase (Decrease)		2024	2023	Increase (Decrease)
Equivalent Barrels (mboed)
Eagle Ford	~~127~~153	~~144~~156	(122)	%	140	150	(7)	%
Bakken	~~105~~107	95108	11(1)	%	106	102	4	%
Permian	4847	4540	718	%	47	43	9	%
Oklahoma	4542	5550	(1816)	%	44	52	(15)	%
Other United States	12	2	~~(50)~~—	%	2	2	—	%
Total United States	~~326~~351	~~341~~356	(41)	%	339	349	(3)	%

	Three Months Ended March 31, 2024
	Three Months Ended June 30, 2024
Sales Mix - U.S. Resource Plays	Eagle Ford		Bakken		Permian		Oklahoma		Total
Crude oil and condensate	5153	%	6563	%	5955	%	2116	%	5352	%
NGLs	24	%	2022	%	2123	%	2933	%	2324	%
Natural gas	2523	%	15	%	2022	%	5051	%	24	%

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	Three Months Ended March 31,
	Three Months Ended June 30,		Six Months Ended June 30,
Drilling Activity - U.S. Resource Plays (a)	2024	2023	2024	2023
Gross Operated
Eagle Ford:
Wells drilled to total depth	4240	3530	82	65
Wells brought to sales	2763	3649	90	85
Bakken:
Wells drilled to total depth	1727	1827	44	45
Wells brought to sales	1817	1723	35	40
Permian:
Wells drilled to total depth	810	86	18	14
Wells brought to sales	421	8	25	16
Oklahoma:
Wells drilled to total depth	32	13	5	4
Wells brought to sales	—	5—	—	5

(a)Includes drilling activity operated under joint development agreements where we have a working interest in the well.

International

In our International segment, we own interests in multiple facilities in E.G. This includes a 64% operated working interest in the Alba field, located offshore E.G., which is consolidated in our financial statements on a pro rata basis. We also own interests in several facilities onshore E.G. which are accounted for as equity method investments. This includes a 52% interest in Alba Plant LLC, which operates aan LPG processing plant; a 56% interest in EG LNG, which operates a 3.7 mmta LNG production facility; and a 45% interest in AMPCO, which operates a methanol plant. For additional information on our interests and their operations, refer to Items 1. and 2. Business and Properties in our 2023 Annual Report on Form 10-K.

As described in Market Conditions, prior to 2024, we primarily sold natural gas to equity method investees via Gas Sales Agreements (GSA’s) in the form of feedstock for LNG and methanol production at long-term fixed prices. AMPCO markets methanol at market prices, and EG LNG marketed LNG on a market-based contract indexed to Henry Hub pricing. We also sell a certain amount of natural gas for local electricity generation at a long-term fixed price. Whereas the GSA with AMPCO continues into 2026, beginning January 1, 2024, the GSA to sell natural gas to EG LNG, and the contract for EG LNG to sell LNG indexed to Henry Hub pricing, expired and were replaced by a new series of agreements. The Alba field partners no longer sell natural gas under a GSA to EG LNG; instead, EG LNG earns a tolling fee to provide liquefaction, storage and product handling services as well as a profit share, and as an Alba partner, we now market our share of LNG to third parties indexed at global LNG prices. We also assume responsibility for shrink and plant losses during liquefaction, which results in lower reported net production and sales volumes, and we are subject to a lifting schedule for our equity LNG cargos, which may place us in an underlift/overlift position depending on timing. In our consolidated statements of income, our sales of LNG to third parties isare included in revenues from contracts with customers. The fees payable to EG LNG are recorded as related party shipping, handling and other operating expense, and our share of this income earned by EG LNG is included in income from equity method investments. In addition to servicing the Alba field, EG LNG processes additional third-party gas from the Alen field under a combination of a tolling fee and profit-sharing arrangement, the benefits of which are also included in our respective share of income from equity method investments.

In ~~the first quarter of~~ 2024, our initial sales of LNG under this new contract occurred. ~~Our~~For the three months ended June 30, 2024, our net sales volumes of LNG were 78109 mmcfd, at ~~the~~an average realized price of $78.2152 per mcf. We recorded $51 84 million in revenue for these sales, and incurred expense of $15 12 million to EG LNG for their services. We recorded $39 26 million in income from equity method investments infor the ~~quarter,~~period and International segment income of $82 79 million. ~~We also held a positive balance of LNG inventory at quarter end, that was included in our April sales.~~

For the six months ended June 30, 2024, our net sales volumes of LNG were 93 mmcfd, at the average realized price of $7.97 per mcf. We recorded $135 million in revenue for these sales, and incurred expense of $27 million to EG LNG for their services. We recorded $65 million in income from equity method investments for the period and International segment income of $161 million.

In 2024, due to the expected arbitrage between LNG and methanol pricing, we have chosen to optimize our E.G. integrated gas operations by redirecting a portion of Alba field natural gas from AMPCO to the LNG production facility operated by EG LNG.

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The table below provides details regarding net sales volumes for our operations within this segment:

	Three Months Ended March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
Net Sales Volumes	2024	2023	Increase (Decrease)		2024	2023	Increase (Decrease)
Crude and oil condensate (mbbld)	115	118	—(38)	%	8	9	(11)	%
NGLs (mbbld)	65	65	—	%	5	6	(17)	%
Natural gas, sold as gas (mmcfd)	7882	~~232~~186	(6656)	%	80	209	(62)	%
Natural gas, sold as LNG (mmcfd)	78109	—	—	%	93	—	—	%
Total natural gas (mmcfd)	~~156~~191	~~232~~186	~~(33)~~3	%	173	209	(17)	%
Total International (mboed)	4342	5644	(235)	%	42	50	(16)	%
Equity Method Investees
LNG (mtd)(a)	~~388~~—	21,~~112~~716	(82100)	%	194	1,913	(90)	%
Methanol (mtd)	~~935~~954	1,~~378~~047	(329)	%	945	1,212	(22)	%
Condensate and LPG (boed)	75,~~630~~998	86,~~817~~614	(139)	%	6,814	7,709	(12)	%

(a)LNG sales from equity method investees in 2024 represents final residual volumes sold under the contract terms in place prior to January 1, 2024.

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~~payment of ~~share repurchases~~dividends. Commodity prices experienced significant volatility in 2022 after the Russia/Ukraine conflict began and this has continued into 2024. Events in the Middle East have added further volatility to energy prices and the outlook for that region remains extremely uncertain. Economic headwinds should diminish moving forward as inflation appears to have peaked and interest rates could fall later in 2024. However, the tailwind to annual energy demand growth from the post-COVID recovery has likely run its course and annual growth should be more in line with the long-term trend moving forward. Ongoing OPEC+ petroleum supply limitations and economic sanctions involving producer countries continue to add uncertainty to the price outlook. We expect commodity price volatility to continue given the complex global dynamics of supply and demand that exist in the market. Refer to Item 1A. Risk Factors in our 2023 Annual Report on Form 10-K for further discussion on how volatility in commodity prices could impact us.

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 ~~first~~second quarter and first six months of 2024 and 2023:

	Three Months Ended March 31,
	Three Months Ended June 30,						Six Months Ended June 30,
	2024		2023		Increase (Decrease)		2024		2023		Increase (Decrease)
Average Price Realizations(a)
Crude oil and condensate (per bbl)	$	7579.3912	$	7472.6949	19	%	$	77.31	$	73.57	5	%
NGLs (per bbl)	2221.2418		2418.2772		~~(8)~~13	%	21.67		21.25		2	%
Natural gas (per mcf)	1.9742		21.9589		(3325)	%	1.69		2.43		(30)	%
Benchmarks
WTI crude oil average of daily prices (per bbl)	$	7680.9166	$	7573.9956	110	%	$	78.81	$	74.77	5	%
Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)	7883.8100		7774.3693		211	%	80.90		76.14		6	%
Mont Belvieu NGLs (per bbl)(b)	2322.6791		2520.3349		~~(7)~~12	%	23.29		22.91		2	%
Henry Hub natural gas settlement date average (per mmbtu)	21.2489		32.4210		(3510)	%	2.15		2.76		(22)	%

(a)Excludes gains or losses on commodity derivative instruments.

(b)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.

~~NGLs – The majority of our sales volumes are sold at reference to Mont Belvieu prices.~~30

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NGLs – 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 and natural gas for the ~~first~~second quarter and first six months of 2024 and 2023:

	Three Months Ended March 31,
	Three Months Ended June 30,						Six Months Ended June 30,
	2024		2023		Increase (Decrease)		2024		2023		Increase (Decrease)
Average Price Realizations
Crude oil and condensate (per bbl)	$	6157.8631	$	5853.5764	67	%	$	60.34	$	56.46	7	%
NGLs (per bbl)	1.00		1.00		—	%	1.00		1.00		—	%
Natural gas, sold as gas (per mcf)	0.24		0.24		—	%	0.24		0.24		—	%
Natural gas, sold as LNG (per mcf)	78.2152		—		—	%	7.97		—		—	%
Average total natural gas (per mcf)	$4.96	~~3.71~~	$	0.24	1,~~446~~967	%	4.40		0.24		1,733	%
Benchmark
Brent (Europe) crude oil (per bbl)(a)	$	83.00	$	81.17	2	%
Brent (Europe) crude oil (per bbl) (a)	$	84.65	$	78.32	8	%	$	83.83	$	79.75	5	%
TTF (Europe) natural gas (per mmbtu) (b)	89.7998		1611.7234		(4712)	%	9.40		14.01		(33)	%
JKM (East Asia) natural gas (per mmbtu) (c)	911.5010		1711.9812		~~(47)~~—	%	10.33		14.49		(29)	%

(a)Average of monthly prices obtained from the United States Energy Information Agency website.

(b)Average of monthly prices obtained from NYMEX Exchange (expressed in $).

(c)Average of monthly prices obtained from Tokyo Commodity Exchange (expressed in $).

Crude oil and condensate – Alba field liquids production is primarily condensate. We generally sell our 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 -term contract. Alba Plant LLC extracts NGLs and 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 to AMPCO and EG LNG.

NGLs – Wet gas is sold to Alba Plant LLC at a fixed-price long -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 – Prior to 2024, dry natural gas, processed by Alba Plant LLC on behalf of the Alba Unit Parties, was sold by the Alba field to our equity method investees EG LNG and AMPCO at fixed-price contracts resulting in realized prices not tracking market price. EG LNG ~~sold~~marketed LNG on a market-based contract and AMPCO markets methanol at market prices. The gas sales contract between Alba Unit and EG LNG expired on December 31, 2023. The gas sales contract with AMPCO expires in 2026.

In March 2023, we announced the signing of a Heads of Agreement (“HOA”) to progress the development of the Equatorial Guinea Regional Gas Mega Hub. In October 2023, we announced the signing of a 5-year firm LNG sales agreement for a portion of our Alba gas liquefied at EG LNG. The contract was effective January 1, 2024, and features a pricing structure linked to the Dutch Title Transfer Facility (“TTF”) index, providing us with significant incremental exposure to the European LNG market. In addition, we have entered into an agreement to sell the remainder of our 2024 LNG volumes under a contract linked to the Japan/Korea Marker (“JKM”).

In addition to processing Alba Unit gas, Alba Plant LLC and EG LNG process third-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.

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Results of Operations

Three Months Ended ~~March~~June 3130, 2024 vs. Three Months Ended ~~March~~June 3130, 2023

Revenues from contracts with customers are presented by segment in the table below:

	Three Months Ended March 31,
	Three Months Ended June 30,
(In millions)	2024		2023
Revenues from contracts with customers
United States	$	1,~~422~~551	$	1,~~503~~440
International	~~116~~115		6444
Segment revenues from contracts with customers	$	1,~~538~~666	$	1,~~567~~484

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 to
(In millions)	Three Months Ended ~~March~~June 3130, 2023		Price Realizations		Net Sales Volumes		Three Months Ended ~~March~~June 3130, 2024
United States Price/Volume Analysis
Crude oil and condensate	$	1,~~185~~195	$	11110	$	~~(16)~~11	$	1,~~180~~316
NGLs	~~169~~156		~~(14)~~19		(412)		~~151~~163
Natural gas	~~139~~86		(4321)		~~(10)~~—		8665
Other sales(a)	103						57
Total	$	1,~~503~~440					$	1,~~422~~551
International Price/Volume Analysis
Crude oil and condensate	$	5739	$	32	$	1(13)	$	6128
NGLs	1—		—		—		1—
Natural gas, sold as gas	54		—		(32)		2
Natural gas, sold as LNG	—		5184		—		5184
Natural gas	54		5184		(32)		5386
Other sales	1						1
Total	$	6444					$	~~116~~115

(a)Includes revenue from commodity volumes purchased for resale.

Net gain ~~(loss)~~ on ~~commodity~~disposal ~~derivatives in the first quarter~~ of ~~2024~~assets ~~was~~we anrecognized ~~unrealized~~a ~~loss~~gain of $2410 million, ~~compared to realized and unrealized gains of $15 million for the same period~~ in ~~2023. We have commodity derivative contracts which settle against~~ the ~~NYMEX~~second ~~WTI~~quarter ~~index.~~of We2024 ~~record~~on ~~commodity derivative gains/losses as~~ the ~~index~~sale ~~pricing~~of ~~and~~a ~~forward~~legacy ~~curves~~royalty ~~change~~interest ~~each~~in ~~period. See Note 8 to~~ the ~~consolidated~~state ~~financial~~of ~~statements for further information~~California.

~~Income~~Production ~~from~~expense ~~equity~~increased ~~method investments decreased~~ $412 million in the ~~first~~second quarter of 2024, when compared to the ~~first~~same ~~quarter~~period ~~of 2023, primarily due to decreased sales volume as a result of the new agreement that became effective~~ in January 2024, whereby EG LNG no longer markets LNG directly but instead processes LNG for a tolling fee and profit sharing, as well as lower prices realized by our equity method investees during the first quarter of 20242023.

~~Production~~The ~~expenses~~following ~~for~~table ~~the~~provides ~~first~~production ~~quarter~~expense ofand ~~2024~~production ~~increased~~expense byrates ~~$20~~for ~~million~~each ~~compared to the same period in 2023, primarily due to increased workover activities during the first quarter of 2024.~~ segment:


	Three Months Ended June 30,
($ in millions; rate in $ per boe)	2024		2023		Increase (Decrease)		2024		2023		Increase (Decrease)
Production Expense and Rate	Expense						Rate
United States	$	198	$	191	4	%	$	6.21	$	5.88	6	%
International	$	18	$	23	(22)	%	$	4.46	$	5.72	(22)	%

Shipping, handling and other operating increased $14 million in the second quarter of 2024 when compared to the same period in 2023, primarily as a result of the new agreement that became effective in January 2024, whereby EG LNG processes LNG for a tolling fee and profit share which we record as related party shipping, handling and other operating expense.

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Depreciation, depletion and amortization

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:


	Three Months Ended June 30,
($ in millions; rate in $ per boe)	2024		2023		Increase (Decrease)		2024		2023		Increase (Decrease)
DD&A Expense and Rate	Expense						Rate
United States	$	562	$	547	3	%	$	17.57	$	16.88	4	%
International	$	10	$	10	—	%	$	2.61	$	2.42	8	%

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 $60 million in the second quarter of 2024 primarily due to a nonrecurring Eagle Ford severance tax refund of $47 million related to prior years in the second quarter of 2023.

General and administrative expenses increased $28 million in the second quarter of 2024 primarily due to increases in consulting and legal service expenses associated with the Merger, and an increase in the annual employee bonus accrual estimated to payout at the maximum percentage as a result of the Merger.

Net interest and other decreased $12 million in the second quarter of 2024 primarily due to the full repayment of the remaining outstanding borrowings of $1.2 billion on the Term Loan Facility in the first quarter of 2024 and the subsequent issuance of our 2029 Notes and 2034 Notes at lower interest rates. See Note 7 to the consolidated financial statements for further information.

Provision for income taxes increased $18 million in the second quarter of 2024 primarily due to an increase in income before income taxes for the current quarter when compared to the same period in 2023.

Segment Income

Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. See Note 5 to the consolidated financial statements for further details regarding items not allocated to the operating segments.

The following table reconciles segment income to net income:


	Three Months Ended June 30,
(In millions)	2024		2023
United States	$	379	$	365
International	79		30
Segment income	458		395
Items not allocated to segments, net of income taxes	(109)		(108)
Net income	$	349	$	287

United States segment income in the second quarter of 2024 was $379 million of income versus $365 million of income for the same period in 2023. The increase in segment income is a result of the variances described above.

International segment income in the second quarter of 2024 was $79 million of income versus $30 million of income for the same period in 2023. The increase was primarily due to increased revenue from new LNG sales indexed to global prices, partially offset by increased income tax as a result of increased revenue, and increased shipping and handling costs associated with LNG processing and liquefaction.

Items not allocated to segments, net of income taxes in the second quarter of 2024 was a loss of $109 million versus a loss of $108 million for the same period in 2023. The change is primarily a result of the variances in general and administrative expense and net interest and other described above.

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Results of Operations

Six Months Ended June 30, 2024 vs. Six Months Ended June 30, 2023

Revenues from contracts with customers are presented by segment in the table below:


	Six Months Ended June 30,
(In millions)		2024		2023
Revenues from contracts with customers
United States		$	2,973	$	2,943
International		231		108
Segment revenues from contracts with customers		$	3,204	$	3,051

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 to
(In millions)	Six Months Ended June 30, 2023		Price Realizations		Net Sales Volumes		Six Months Ended June 30, 2024
United States Price/Volume Analysis
Crude oil and condensate	$	2,380	$	120	$	(4)	$	2,496
NGLs	325		6		(17)		314
Natural gas	225		(66)		(8)		151
Other sales(a)	13						12
Total	$	2,943					$	2,973
International Price/Volume Analysis
Crude oil and condensate	$	96	$	6	$	(13)	$	89
NGLs	1		—		—		1
Natural gas, sold as gas	9		—		(5)		4
Natural gas, sold as LNG	—		135		—		135
Natural gas	9		135		(5)		139
Other sales	2						2
Total	$	108					$	231

(a)Includes revenue from commodity volumes purchased for resale.

Net gain (loss) on commodity derivatives in the first six months of 2024 was a net loss of $23 million, compared to a net gain of $18 million for the same period in 2023. We have commodity derivative contracts that settle against 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 8 to the consolidated financial statements for further information.

Income from equity method investments decreased $37 million for the first six months of 2024, primarily due to decreased revenue as EG LNG no longer markets LNG directly as a result of the new agreement that became effective in January 2024, as well as lower sales volume by our equity method investees during the first six months of 2024.

Other income for the first six months of 2024 decreased by $15 million compared to the same period in 2023, primarily due to fair value adjustments on liabilities assumed from acquisitions.

Production expenses for the first six months of 2024 increased by $22 million compared to the same period in 2023, primarily due to increased workover activities in our U.S segment.

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The following table provides production expense and production expense rates for each segment:

	Three Months Ended March 31,
	Six Months Ended June 30,
($ in millions; rate in $ per boe)	2024		2023		Increase (Decrease)		2024		2023		Increase (Decrease)
Production Expense and Rate	Expense						Rate
United States	$	~~201~~399	$	~~178~~369	138	%	$	6.7748	$	5.8285	1611	%
International	$	2038	$	2346	(1317)	%	$	54.1380	$	45.5406	13(5)	%

Shipping, handling and other operating expenses increased $21 million in the first six months of 2024, when compared to the same period in 2023, primarily due to increased shipping and handling expenses as a result of the new agreement that became effective in January 2024, whereby EG LNG no longer markets LNG directly but instead processes LNG for a tolling fee and profit sharing which we record as related party shipping, handling and other operating expense.

Depreciation, depletion and amortization

	Three Months Ended March 31,
	Six Months Ended June 30,
($ in millions; rate in $ per boe)	2024		2023		~~2023~~Increase (Decrease)			~~Increase (Decrease)~~2024			2023		~~2024~~Increase (Decrease)			~~2023~~		~~Increase (Decrease)~~
DD&A Expense and Rate	Expense							Rate					~~Rate~~
United States	$	~~500~~1,062	$	1,052	$1	~~505~~	%	~~(1)~~$	17.22	%	$	16.68	$3	~~16.83~~	%	$	~~16.46~~	2	%
International	$	1020	$	22	$(9)	12	%	~~(17)~~$	2.70	%	$	2.41	$12	~~2.79~~	%	$	~~2.41~~	16	%

~~Provision~~Taxes ~~for~~other than income include production, severance and ad valorem taxes, ~~decreased~~primarily ~~$24~~in the U.S., which tend to increase or decrease in relation to revenue and sales volumes. Taxes other than income increased $61 million in the first ~~quarter~~six months of 2024 primarily due to a ~~decrease~~nonrecurring inEagle ~~income~~Ford ~~before~~severance ~~income~~tax ~~taxes~~refund ~~for~~of ~~the~~$47 million ~~current~~related ~~quarter~~to ~~when~~prior ~~compared~~years toin the ~~same~~first ~~period~~six inmonths of 2023.

General and administrative expenses increased $32 million in the first six months of 2024, primarily due to increases in consulting and legal service expenses associated with the Merger, and an increase in the annual employee bonus accrual estimated to payout at the maximum percentage as a result of the Merger.

Net interest and other decreased $25 million in the first six months of 2024 primarily due to the repayment of $300 million of the outstanding borrowings on the Term Loan Facility in the fourth quarter of 2023, the full repayment of the remaining outstanding borrowings of $1.2 billion on the Term Loan Facility in the first quarter of 2024 and the subsequent issuance of our 2029 Notes and 2034 Notes at lower interest rates. Additionally, beginning in the third quarter of 2023, we transitioned our credit facility borrowings to commercial paper borrowings at lower interest rates. See Note 7 to the consolidated financial statements for further information.

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Segment Income

The following table reconciles segment income to net income:

Three Months Ended March 31,

Six Months Ended June 30,

(In millions)

2024

2023

United States

~~334~~713

~~425~~790

International

82161

89119

Segment income

~~416~~874

~~514~~909

Items not allocated to segments, net of income taxes

(~~119~~228)

(97205)

Net income

~~297~~646

~~417~~704

United States segment income infor the first ~~quarter~~six months of 2024 was $~~334~~713 million of income versus $~~425~~790 million of income for the same period in 2023. The decrease in segment income is a result of the variances described above.

International segment income infor the first ~~quarter~~six months of 2024 was $82161 million of income versus $89119 million of income for the same period in 2023. The ~~decrease~~increase was primarily due to ~~lower~~increased revenue from new LNG sales ~~volume~~indexed ~~and~~to ~~lower~~global prices, ~~realized~~partially offset by ~~our~~increased ~~equity~~income ~~method~~tax ~~investees,~~as ~~partially~~a ~~offset~~result byof increased revenue, ~~from~~and ~~new~~increased ~~LNG~~shipping ~~sales~~and ~~indexed~~handling tocosts ~~global~~associated ~~prices~~with LNG processing and liquefaction.

Items not allocated to segments, net of income taxes infor the first ~~quarter~~six months of 2024 was ~~a loss of~~ $~~119~~228 million ~~versus~~of a loss ofversus $97205 million of loss for the same period in 2023. The increase in loss was primarily due to an increase in unrealized net losses on commodity derivatives, variances in ~~the~~general ~~first~~and ~~quarter~~administrative ofexpense ~~2024~~and ~~versus unrealized~~ net ~~gains~~interest onand ~~commodity~~other ~~derivatives~~described ~~in the same period of 2023~~above.

Critical Accounting Estimates

There 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, 2023.

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Cash Flows

The following table presents sources and uses of cash and cash equivalents:

	Three Months Ended March 31,
	Six Months Ended June 30,
(In millions)	2024		2023
Sources of cash and cash equivalents
Borrowings	$	1,200	$	—
Net cash provided by operating activities	$	1,845	$	1,941
Net cash provided by operating activities	757		865
Borrowings	1,200		200
Proceeds from revolving credit facility	50		~~175~~980
Other	1		11
Equity method investments - return of capital	2		34
Total sources of cash and cash equivalents	$	2,008	$	1,051
Other	11		9
Total sources of cash and cash equivalents	$	3,108	$	3,164
Uses of cash and cash equivalents
Capital expenditures	$	(~~603~~1,268)	$	(~~601~~1,224)
Change in capital accrual	~~117~~136		6958
Debt repayments	(1,200)		(70270)
Repayments of revolving credit facility	(4350)		(~~175~~980)
Shares repurchased under buyback programs	(285)		(334)
Repayments of commercial paper borrowings, net	(125)		—
Dividends paid	(64)		(63)
Shares repurchased under buyback programs	(516)		(706)
Dividends paid	(127)		(125)
Withholding tax on stock-based incentive awards	(18)		(30)
Other	(14)		(3)
Acquisition, net of cash acquired	(4)		—
Total uses of cash and cash equivalents	$	(2,114)	$	(1,207)
Other	(14)		(6)
Total uses of cash and cash equivalents	$	(3,186)	$	(3,283)

Sources of cash and cash equivalents

Cash flows generated from operating activities during the first ~~quarter~~six months of 2024 were 125% lower compared to the same period in 2023, primarily asdue ato ~~result~~decreased ofdividends ~~lower~~received ~~realized~~from ~~natural~~equity ~~gas~~method ~~prices~~investees, ~~and~~primarily ~~sales~~EG ~~volumes~~LNG. inThe ~~our~~decrease USwas ~~segment,~~ partially offset by higher realized crude oil prices in the US segment and increased revenue from new LNG sales indexed to global prices in our International segment, in addition to an increase in working capital in the first six months of 2024 compared to the same period in 2023.

On March 28, 2024, we completed a public offering of $1.2 billion aggregate principal amount of unsecured senior notes (2029 Notes and 2034 Notes). Net proceeds received totaled approximately $1.2 billion and together with cash on hand were used to repay $1.2 billion outstanding borrowings under our Term Loan Facility. See Note 7 and Liquidity and Capital Resources section below for further information.

We utilize our commercial paper program to fund our short -term working capital requirements. As of ~~March~~June 3130, 2024, we have net outstanding commercial paper borrowings of $~~450~~325 million. See Note 7 for further information.

Uses of cash and cash equivalents

During the first ~~three~~six months of 2024, we repurchased approximately 1119 million shares of our common stock pursuant to the share repurchase program at a cost of $~~285~~516 million and paid dividends of $64127 million.

The following table shows capital expenditures by segments:

	Three Months Ended March 31,
	Six Months Ended June 30,
(In millions)	2024		2023
United States	$	~~598~~1,258	$	~~597~~1,217
International	14		2
Not allocated to segments	46		25
Total capital expenditures	~~603~~1,268		~~601~~1,224

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Liquidity and Capital Resources

The following liquidity and capital resources discussion is qualified in its entirety by the limitations contained in the Merger Agreement. Under the Merger Agreement, we are subject to restrictions and limitations that, among other things, preclude us from assuming additional debt, issuing additional equity or debt, making certain capital expenditures and executing certain asset transactions, and entering certain merger, liquidation or disposition transactions. Upon completion of the Merger and on the closing date, we will terminate all commitments under our Revolving Credit Facility and repay in full all obligations with respect to our Revolving Credit Facility and commercial paper program.

Capital Resources and Available Liquidity

Our main sources of liquidity are cash and cash equivalents, internally generated cash flow from operations, capital market transactions, our Revolving Credit Facility and our commercial paper program. At ~~March~~June 3130, 2024, we had approximately $2.23 billion of liquidity consisting of $4977 million in cash and cash equivalents and $2.12 billion available under our Revolving Credit Facility. Under the Merger Agreement, however, we are not permitted to exceed an aggregate $1.5 billion in outstanding borrowings under our commercial paper program or Revolving Credit Facility except in emergency situations provided that we notify ConocoPhillips of any such borrowings as soon as reasonably practicable.

Our working capital requirements are supported by our cash and cash equivalents, our Revolving Credit Facility and our commercial paper program. WeSubject to certain restrictions in the Merger Agreement, we may issue commercial paper, draw on our Revolving 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 17 to the consolidated financial statements for further discussion of how our commitments and contingencies could affect our available liquidity. ~~General~~Additionally, we expect our available liquidity to be impacted by a number of non-recurring costs associated with the Merger Agreement including, among others, fees and expenses from financial advisors and other advisors and representatives, certain employment-related costs relating to employees of Marathon Oil and filing fees due in connection with required regulatory filings. Some of these costs have already been incurred or may be incurred regardless of whether the Merger is completed. Further, general economic conditions, commodity prices and financial, business and other factors could affect our operations and our ability to access the capital markets.

We maintain 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, 2023 for a discussion of how a downgrade in our credit ratings could affect us.

We may incur additional debt 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, 2023 for a further discussion of how our level of indebtedness could affect us.

Credit Arrangements and Borrowing Developments

On March 28, 2024, we completed a public offering of $1.2 billion aggregate principal amount of unsecured senior notes consisting of $600 million aggregate principal amount of 5.30% 2029 Notes and $600 million aggregate principal amount of 5.70% 2034 Notes. Interest on the senior notes is payable semi-annually beginning October 1, 2024. We may redeem some or all of the senior notes at any time at the applicable redemption price, plus accrued interest, if any. Net proceeds received totaled approximately $1.2 billion which were used together with cash on hand to repay $1.2 billion outstanding borrowings under our Term Loan Facility. See Note 7 to the consolidated financial statements for further information.

As of ~~March~~June 3130, 2024, we had $5.0 billion of total long-term debt outstanding. Long-term debt due within one year consists of $200 million 2.10% of sub-series ~~2017A~~2017 A-2 bonds and $200 million 2.125% of sub-series ~~2017B~~2017 B-1 bonds, both of which feature a mandatory put on July 1, 2024. In addition, as of ~~March 31~~June 30, 2024, we had outstanding commercial paper borrowings of $~~450~~325 million.

As of March 31, 2024, we had an immaterial balance outstanding under our Revolving Credit Facility. Our Revolving Credit Facility includes 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 25% at March 31, 2024. See Note 7 to the consolidated financial statements for further information. 38

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As of June 30, 2024, we had no outstanding borrowings under our Revolving Credit Facility. Our Revolving Credit Facility includes 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 24% at June 30, 2024. See Note 7 to the consolidated financial statements for further information.

Refer to our 2023 Annual Report on Form 10-K for a listing of our long-term debt maturities.

Other Sources of Liquidity

We have an effective universal shelf registration statement filed with the SEC pursuant to which we, as a “well-known seasoned issuer” for purposes of SEC rules, subject to market conditions and certain restrictions in the Merger Agreement, are permitted to issue and sell an indeterminate amount of various types of debt, equity securities and other capital instruments, if and when necessary or perceived by us to be opportune, in one or more public offerings.

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Capital Requirements

Share Repurchase Program

Our Board of Directors has authorized a share repurchase program, however, upon the announcement of the Merger Agreement, we suspended our stock repurchase activity as we are subject to certain restrictions to our ability to repurchase, redeem or otherwise acquire our capital stock. Our remaining authorization at ~~March~~June 3130, 2024 was approximately $21.08 billion.

Subsequent to the quarter, we repurchased approximately $110 million of shares of our common stock through May 1, 2024.

Dividends

On ~~April~~July 2431, 2024, our Board of Directors approved a dividend of $0.11 per share payable ~~June~~on September 10, 2024 to stockholders of record at the close of business on ~~May~~August 1521, 2024. Pursuant to the terms of the Merger Agreement, we are prevented from increasing our quarterly per share dividend in excess of $0.11 per quarter.

Income Taxes

As described in Note 6 to the consolidated financial statements, the IRA was signed into law during 2022. Under current law and guidance, we are subject to the corporate book minimum tax in 2024. The U.S. Department of the Treasury and the IRS are expected to release further regulations and interpretive guidance implementing the legislation contained in the IRA. 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.

Other Contractual Cash Obligations

As of ~~March~~June 3130, 2024, material changes to our contractual cash obligations compared to December 31, 2023 include the addition of $1.2 billion senior notes issued during the first quarter of 2024 and the full repayment of $1.2 billion outstanding borrowings under our Term Loan Facility during the same period.

As described in Note 17 to the consolidated financial statements below, we have entered into a consent decree with the EPA and Department of Justice that includes a civil penalty of $65 million, which we anticipate paying in 2024.

Additionally, future contractual cash obligations may include liabilities in connection with the Merger Agreement. Certain costs may be incurred even if the Merger is not consummated.

Other than the items set forth above, there are no material changes to our consolidated cash obligations to make future payments under existing contracts, as disclosed in our 2023 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 of 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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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 2023 Annual Report on Form 10-K. See Note 17 to the consolidated financial statements for a description of other contingencies.

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, as amended (the “Exchange Act”). All statements, other than statements of historical fact, including without limitation statements regarding our future performance, business strategy, 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, expectations with respect to the consent decree with the EPA and Department of Justice and statements regarding management’s other plans and objectives for future operations, are forward-looking statements. In addition, many forward-looking statements may be identified by the use of forward-looking terminology such as “anticipates,” “believes,” “continue,” “could,” “estimates,” “expects,” “forecast,” “future,” “guidance,” “intend,” “may,” “outlook,” “plans,” “positioned,” “projects,” “seek,” “should,” “targets,” “will,” “would” or similar words indicating that future outcomes are uncertain. While we believe that our assumptions concerning future events are reasonable, these expectations may not prove to be correct. A number of factors could cause results to differ materially from those 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, including liquified natural gas, and the resulting impact on price;

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•changes in expected reserve or production levels;

•changes in political or 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 and other global and domestic political, economic or diplomatic developments;

•capital available for exploration and development;

•risks related to our hedging activities;

•voluntary or 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;

•drilling and operating risks;

•lack of, or disruption in, access to storage capacity, pipelines or other transportation methods;

•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 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;

•unforeseen hazards such as weather conditions, a health pandemic, acts of war or terrorist acts and the governmental or military response thereto;

•the impacts of supply chain disruptions that began during the COVID-19 pandemic and 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;

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•changes in safety, health, environmental, tax, currency and other regulations, or requirements or initiatives including those addressing the impact of global climate change, air emissions or water management;

•our ability to achieve, reach or otherwise meet initiatives, plans or ambitions with respect to ESG matters;

•our ability to pay dividends and make share repurchases;

•our ability to secure increased exposure to global LNG market prices and progress on the E.G. Gas Mega Hub;

•impacts of the IRA;

•the risk that assets we acquire do not perform consistent with our expectations, including with respect to future production or drilling inventory;

•other geological, operating and economic considerations; ~~and~~

•risks and uncertainties associated with the proposed Merger with ConocoPhillips, including the following:

◦ConocoPhillips’ ability to successfully integrate Marathon Oil’s businesses and technologies, which may result in the combined company not operating as effectively and efficiently as expected; the risk that the expected benefits and synergies of the Merger may not be fully achieved in a timely manner, or at all;

◦the risk that ConocoPhillips or Marathon Oil will be unable to retain and hire key personnel and maintain relationships with their suppliers and customers; the risk associated with Marathon Oil’s ability to obtain the approval of its stockholders required to consummate the Merger and the timing of the closing of the Merger, including the risk that the conditions to the Merger are not satisfied on a timely basis or at all or the failure of the Merger to close for any other reason or to close on the anticipated terms, including the anticipated tax treatment;

◦the risk that any regulatory approval, consent or authorization that may be required for the Merger is not obtained or is obtained subject to conditions that are not anticipated; the occurrence of any event, change or other circumstance that could give rise to the termination of the Merger;

◦unanticipated difficulties, liabilities or expenditures relating to the Merger;

◦the effect of the pendency or completion of the Merger on the parties’ business relationships and business operations generally;

◦the effect of the pendency of the Merger on the parties’ common stock prices and uncertainty as to the long-term value of ConocoPhillips’ or Marathon Oil’s common stock;

◦risks that the Merger disrupts current plans and operations of ConocoPhillips or Marathon Oil and their respective management teams and potential difficulties in hiring or retaining employees as a result of the Merger; and

•the risk factors, forward-looking statements and challenges and uncertainties described in our 2023 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. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements contained throughout this report.

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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~~However, ~~Note~~under 8the ~~and~~Merger ~~Note~~Agreement, 9we toare ~~the~~subject ~~consolidated~~to ~~financial~~limitations ~~statements~~on ~~for~~our ~~detail~~ability ~~relating~~ to ~~our~~enter ~~open~~into ~~commodity~~new derivative ~~positions~~transactions, ~~including~~which ~~underlying~~may ~~notional~~prevent ~~quantities,~~us ~~how~~from ~~they~~using ~~are~~financial ~~reported~~derivatives into ~~our~~manage ~~consolidated~~the ~~financial~~risks ~~statements~~related ~~and~~to ~~how~~commodity ~~their~~price ~~fair~~and ~~values~~interest ~~are~~rate ~~measured~~fluctuations.

See Note 8 and Note 9 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 ~~March~~June 3130, 2024, we had open commodity derivatives related to crude oil and natural gas. Based on the ~~March~~June 3130, 2024 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 ~~March~~June 3130, 2024		Hypothetical Price Increase of 10%		Hypothetical Price Decrease of 10%
Derivative asset (liability) - Crude Oil	$	—	$	(2515)	$	1912
Derivative asset (liability) - Natural Gas	1		(5)		7
Total	$	1	$	(20)	$	19

Interest Rate Risk

At ~~March~~June 3130, 2024, our portfolio of current and long-term debt is comprised of floating rate debt and fixed-rate instruments. Our Revolving Credit Facility and commercial paper borrowings are floating rate debt instruments, which exposes us to the risk of earnings or cash flow losses as the result of potential increases in market interest rates. At ~~March~~June 3130, 2024, we had anno ~~immaterial~~ outstanding balance under our Revolving Credit Facility and $~~450~~325 million outstanding borrowings under our commercial paper program. Assuming no change in the amount of floating rate debt outstanding, a hypothetical 100 basis point increase in the average interest rate under our commercial paper borrowings would have increased our annual interest expense by approximately $53 million. Actual results may vary due to changes in the amount of floating rate debt outstanding.

At ~~March~~June 3130, 2024, we had $5.0 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 ~~March~~June 3130, 2024, 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 SOFR 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 hedges to the following as of ~~March~~June 3130, 2024:

(In millions)			Fair Value at ~~March~~June 3130, 2024						Hypothetical Interest Rate Increase of 10%												Hypothetical Interest Rate Decrease of 10%
Interest rate asset - designated as cash flow hedges			$	1918					$	2221											$	1716

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 ~~March~~June 3130, 2024.

During the ~~first~~second ~~three~~quarter ~~months~~ of 2024, there were no changes in our internal control over financial reporting that have materially affected, or were reasonably likely to materially affect, our internal control over financial reporting.

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Part II – OTHER INFORMATION

Item 1. Legal Proceedings

~~We have received~~ Notices of Violation (“NOVs”) from the EPA related to alleged violations of the Clean Air 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. The resolution of the enforcement action will likely include monetary sanctions, for which we maintain an updated accrual as matters progress, and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. Based on our discussions with the EPA and Department of Justice since the filing of our Form 10-K for the year ended December 31, 2023, we do not believe resolution of this matter will have a material adverse effect on our business or operations. We have in good faith begun implementing select enhanced compliance requirements associated with likely settlement terms and costs to continue this effort are already fully contemplated in our previously announced 2024 capital budget. There remains uncertainty as to the ultimate result of this matter and it is possible the result could be materially different from our expectations and our accrual.

We received Notices of Violation (“NOVs”) from the Environmental Protection Agency (the “EPA”) ~~relating~~related to alleged violations of the Clean Air Act ~~violations~~with ~~following~~respect ~~flyovers~~to ~~conducted~~our inoperations ~~2020~~on the Fort Berthold Indian Reservation between 2015 and ~~2022~~2019. ~~over~~On ~~certain~~July of10, ~~our~~2024, ~~oil~~we entered into a consent decree with the EPA and ~~gas~~Department ~~facilities~~of inJustice ~~New~~to ~~Mexico~~fully resolve this matter. The ~~notices~~consent ~~involve~~decree ~~alleged~~is ~~emission~~subject ~~and~~to ~~permitting~~a ~~violations~~30-day public comment period before it may be considered for entry by the court. WeThe ~~have~~consent ~~initiated~~decree ~~discussions~~will require the completion of mitigation projects, implementation of specific injunctive relief, and payment of a $65 million civil penalty with substantially all of that civil penalty accrued in our previously filed quarterly report for the ~~EPA~~period toending ~~resolve~~March ~~these~~31, ~~matters~~2024. AsIn 2022, we ~~are~~began ~~still~~early ~~investigating~~implementation ~~these~~of ~~allegations,~~the weinjunctive requirements associated with likely settlement terms and are ~~unable~~scheduled to ~~estimate~~complete ~~the~~this ~~potential~~work ~~loss~~in 2025. The total cost associated with ~~this~~the ~~matter,~~injunctive ~~however~~relief is estimated to be approximately $177 million, itbut isover ~~reasonably~~70% ~~possible~~of that cost has been incurred or included in the ~~resolution~~previously announced 2024 capital budget with the remaining amount to be spent by the end of 2025. The consent decree sets forth a detailed compliance schedule with deadlines for achievement of milestones through at least 2026. The consent decree further contains requirements for ongoing permitting, inspection and monitoring, maintenance, auditing, and reporting. Findings from such inspection, monitoring and auditing activities may result in adecisions ~~fine~~to ortemporarily ~~penalty~~shut in ~~excess~~or ofreduce ~~$300,000~~production from certain wells and facilities.

We have cooperated fully with the EPA, including collecting and sharing extensive data to resolve this matter. The vast majority of emission reductions are being achieved by Marathon Oil’s voluntary commitment to incorporate industry-leading technologies, like our new lowest emitting automated facilities (LEAF). We do not admit liability regarding any of the allegations in the complaint associated with the consent decree and elected to resolve the allegations in a negotiated settlement rather than litigation. We do not believe that the mitigation expenditures, penalties, and injunctive relief that resulted from this settlement will have a material adverse effect on either our business or operations or the previously announced Merger Agreement with ConocoPhillips.

We have received NOVs from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 and 2022 over certain of our oil and gas facilities in New Mexico. The notices involve alleged emission and permitting violations. As previously disclosed, we have been in discussions with the EPA to resolve these matters. In order to fully resolve these matters, effective July 25, 2024, we entered into a consent agreement with the EPA pursuant to which we agreed to pay a civil penalty in the amount of $265,000. We do not believe that any penalty or corrective action expenditures that may result from this matter will have a material adverse effect on our financial position, results of operation or cash flows.

Other than the items set forth above, there have been no significant changes to Item 3. Legal Proceedings in our 2023 Annual Report on Form 10-K. See Note 17 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 2023 Annual Report on Form 10-K.

Item 1A. Risk Factors

WeDue ~~are subject~~ to ~~various~~the ~~risks~~proposed ~~and~~Merger ~~uncertainties~~with inConocoPhillips, ~~the~~there ~~course~~have ofbeen ~~our~~material ~~business. In~~changes ~~addition~~ to the ~~other~~risk ~~information~~factors ~~set~~included ~~forth~~under inPart ~~this~~I, ~~Quarterly~~Item 1A of the Corporation’s Annual Report on Form 10-Q,K for the ~~reader~~year ~~should~~ended ~~carefully~~December ~~consider~~31, ~~the~~2023. For a complete discussion of Marathon Oil’s risk factors, ~~discussed~~refer to the section entitled Risk Factors in Part I, Item 1A. Risk Factors in our ~~2023~~ Annual Report on Form 10-K. ~~There~~for ~~have been no material changes or updates to~~ the ~~risk~~year ~~factors~~ended ~~previously~~December ~~disclosed~~31, ~~in our~~ 2023 ~~Annual~~and ~~Report~~the onfollowing ~~Form~~risk ~~10-K.~~factors:

Failure to complete the Merger could negatively impact the price of shares of Marathon Oil common stock, as well as Marathon Oil’s future businesses and financial results.

The Merger Agreement contains a number of conditions that must be satisfied or waived prior to the completion of the Merger. There can be no assurance that all of the conditions to the completion of the Merger will be so satisfied or waived. If these conditions are not satisfied or waived, ConocoPhillips and Marathon Oil will be unable to complete the Merger. If the Merger is not completed for any reason, including the failure to receive the required approval of the Marathon Oil stockholders, Marathon Oil’s business and financial results may be adversely affected, including as follows:

•Marathon Oil may experience negative reactions from the financial markets, including negative impacts on the market price of Marathon Oil common stock;

•the manner in which industry contacts, business partners and other third parties perceive Marathon Oil may be negatively impacted, which in turn could affect Marathon Oil’s marketing operations or its ability to compete for new business or obtain renewals in the marketplace more broadly;

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•Marathon Oil may experience negative reactions from employees; and

•Marathon Oil will have expended time and resources that could otherwise have been spent on its existing business and the pursuit of other opportunities that could have been beneficial to the company, and Marathon Oil’s ongoing business and financial results may be adversely affected.

In addition to the above risks, if the Merger Agreement is terminated and the Marathon Oil board seeks an alternative transaction, Marathon Oil’s stockholders cannot be certain that Marathon Oil will be able to find a party willing to engage in a transaction on more attractive terms than the Merger. If the Merger Agreement is terminated under specified circumstances, Marathon Oil may be required to pay ConocoPhillips a termination fee of up to $557 million.

ConocoPhillips and Marathon Oil will be subject to business uncertainties while the Merger is pending, which could adversely affect their respective businesses.

Uncertainty about the effect of the Merger on employees, industry contacts and business partners may have an adverse effect on ConocoPhillips and Marathon Oil. These uncertainties may impair ConocoPhillips’ and Marathon Oil’s ability to attract, retain and motivate key personnel until the Merger is completed and for a period of time thereafter and could cause industry contacts, business partners and others that deal with ConocoPhillips and Marathon Oil to seek to change their existing business relationships with ConocoPhillips and Marathon Oil, respectively. Employee retention at Marathon Oil may be particularly challenging during the pendency of the Merger, as employees may experience uncertainty about their roles with ConocoPhillips following the Merger. In addition, the Merger Agreement restricts Marathon Oil from entering into certain corporate transactions and taking other specified actions without the consent of ConocoPhillips, and generally requires each party to continue its operations in the ordinary course, until completion of the Merger. These restrictions may prevent ConocoPhillips and Marathon Oil from pursuing attractive business opportunities that may arise prior to the completion of the Merger. The foregoing may negatively affect the businesses, operations and financial results of each party during the pendency of the Merger and may continue to affect the combined company following the completion of the Merger.

Even if ConocoPhillips and Marathon Oil complete the Merger, the combined company may fail to realize all of the anticipated benefits of the Merger.

The success of the Merger will depend, in part, on the combined company’s ability to realize the anticipated benefits and cost savings from combining ConocoPhillips’ and Marathon Oil’s businesses, including operational and other synergies. The anticipated benefits and cost savings of the Merger may not be realized fully or at all, may take longer to realize than expected or could have other adverse effects that ConocoPhillips and Marathon Oil do not currently foresee. Some of the assumptions that ConocoPhillips has made, such as the achievement of operating synergies, may not be realized. The integration process may, for each of ConocoPhillips and Marathon Oil, result in the loss of key employees, the disruption of ongoing businesses or inconsistencies in standards, controls, procedures and policies. There could be potential unknown liabilities and unforeseen expenses associated with the Merger that were not discovered in the course of performing due diligence. The foregoing may negatively affect the combined company’s ongoing business, operations and financial results following the completion of the Merger.

Uncertainties associated with the Merger may cause a loss of management personnel and other key employees, which could adversely affect the future business and operations of the combined company.

ConocoPhillips and Marathon Oil are dependent on the experience and industry knowledge of their officers and other key employees to execute their business plans. Each company’s success until the Merger and the combined company’s success after the Merger will depend in part upon the ability of ConocoPhillips and Marathon Oil to retain key management personnel and other key employees. Current and prospective employees of ConocoPhillips and Marathon Oil may experience uncertainty about their roles within the combined company following the Merger, which may have an adverse effect on the ability of each of ConocoPhillips and Marathon Oil to attract or retain key management and other key personnel. Accordingly, no assurance can be given that the combined company will be able to attract or retain key management personnel and other key employees of ConocoPhillips and Marathon Oil to the same extent that ConocoPhillips and Marathon Oil have previously been able to attract or retain their own employees.

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The integration of Marathon Oil into ConocoPhillips may not be as successful as anticipated.

The Merger involves numerous operational, strategic, financial, accounting, legal, tax and other risks, potential liabilities associated with the acquired businesses, and uncertainties related to design, operation and integration of Marathon Oil’s internal control over financial reporting. Difficulties in integrating Marathon Oil into ConocoPhillips may result in Marathon Oil performing differently than expected, in operational challenges or in the failure to realize anticipated expense-related efficiencies. ConocoPhillips’ and Marathon Oil’s existing businesses could also be negatively impacted by the Merger. Potential difficulties that may be encountered in the integration process include, among other factors:

•the inability to successfully integrate the businesses of Marathon Oil into ConocoPhillips in a manner that permits ConocoPhillips to achieve the full revenue and cost savings anticipated from the Merger;

•complexities associated with managing the larger, more complex, integrated business;

•not realizing anticipated operating synergies;

•integrating personnel from the two companies and the loss of key employees;

•potential unknown liabilities and unforeseen expenses, delays or regulatory conditions associated with the Merger;

•integrating relationships with industry contacts and business partners;

•performance shortfalls at one or both of the companies as a result of the diversion of management’s attention caused by completing the Merger and integrating Marathon Oil’s operations into ConocoPhillips; and

•the disruption of, or the loss of momentum in, each company’s ongoing business or inconsistencies in standards, controls, procedures and policies.

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 ~~March~~June 3130, 2024, of equity securities that are registered by Marathon Oil pursuant to Section 12 of the Securities Exchange Act of 1934:

Period	Total Number of Shares Purchased	Average Price Paid per Share(a)		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(a)(b)
01/01/2024 - 01/31/2024	—	$	—	—	$	2,306,100,537
04/01/2024 - 04/30/2024	3,668,617	$	28.54	3,668,617	$	1,916,404,500
02/01/2024 - 02/29/2024	—	—		—	2,306,100,537
05/01/2024 - 05/31/2024	4,740,559	26.48		4,740,559	1,790,854,737
03/01/2024 - 03/31/2024	10,684,622	26.67		10,684,622	2,021,100,568
06/01/2024 - 06/30/2024	—	—		—	1,790,854,737
Total	108,~~684~~409,~~622~~176	$	2627.6738	108,~~684~~409,~~622~~176

(a)Excludes 1% excise tax on share repurchases.

(b)Refer to our 2023 Annual Report on Form 10-K for historical share repurchase program authorizations and repurchase activity through December 31, 2023. As of ~~March~~June 3130, 2024, we have approximately $21.08 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 ~~March~~June 3130, 2024, were held as treasury stock.

Upon the announcement of the Merger Agreement, we suspended our stock repurchase activity as we are subject to certain restrictions to our ability to repurchase, redeem or otherwise acquire our capital stock.

Item 5. Other Information

During the three months ended ~~March~~June 3130, 2024, 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.

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Item 6. Exhibits

Incorporated by Reference(File No. 001-05153, unless otherwise indicated)

Exhibit Number

Exhibit Description

Form

Exhibit

Filing Date

2.1

Agreement and Plan of Merger, dated as of May 28, 2024, among Marathon Oil Corporation, ConocoPhillips and Puma Merger Sub Corp.

8-K

2.1

5/29/2024

3.1

Restated Certificate of Incorporation of Marathon Oil Corporation

8-K

3.1

6/1/2018

3.2

Marathon Oil Corporation By-laws (amended and restated as of October 25, 2023)

8-K/A

3.21

10/30/2023

3.3

Specimen of Common Stock Certificate

10-K

3.3

2/28/2014

4.1

Indenture, dated as of February 26, 2002, between Marathon Oil Corporation and The Bank of New York Trust Company, N.A., successor in interest to JPMorgan Chase Bank as Trustee, relating to senior debt securities of Marathon Oil Corporation. Pursuant to CFR 229.601(b)(4)(iii), instruments with respect to long-term debt issues have been omitted where the amount of securities authorized under such instruments does not exceed 10% of the total consolidated assets of Marathon Oil. Marathon Oil hereby agrees to furnish a copy of any such instrument to the SEC upon its request

10-K

4.2

2/28/2014

10.1†*

2024 Form of Marathon Oil Corporation 2019 Incentive Compensation Plan Restricted Stock Unit Award Agreement for Section 16 Officers

10.2†*

2024 Form of Marathon Oil Corporation 2019 Incentive Compensation Plan Performance Unit Award Agreement 2024 - 2025 Performance Cycle for Section 16 Officers

10.3†*

2024 Form of Marathon Oil Corporation 2019 Incentive Compensation Plan Performance Unit Award Agreement 2024 - 2026 Performance Cycle for Section 16 Officers

31.1*

Certification of President and Chief Executive Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934

31.2*

Certification of Executive Vice President and Chief Financial Officer pursuant to Rule 13(a)-14 and 15(d)-14 under the Securities Exchange Act of 1934

32.1**

Certification of President and Chief Executive Officer pursuant to 18 U.S.C. Section 1350

32.2**

Certification of Executive Vice President and Chief Financial Officer pursuant to 18 U.S.C. Section 1350

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.

May 2, 2024		MARATHON OIL CORPORATION
August 8, 2024		MARATHON OIL CORPORATION
	By:	/s/ Zach B. Dailey
		Zach B. Dailey
		Vice President, Controller and Chief Accounting Officer
		(Duly Authorized Officer)

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