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	September 30, ~~2022~~2023


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
			For the transition period from _____ to _____

Commission file number 1-1513

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 ~~635,067,840~~585,247,358 shares of Marathon Oil Corporation common stock outstanding as of October 31, ~~2022.~~2023.

MARATHON OIL CORPORATION

Unless the context otherwise indicates, references to “Marathon Oil,” “we,” “our,” or “us” in this Form 10-Q are references to Marathon Oil Corporation, including its wholly owned and majority-owned subsidiaries, and its ownership interests in equity method investees (corporate entities, partnerships, limited liability companies and other ventures over which Marathon Oil exerts significant influence by virtue of its ownership interest).

For certain industry specific terms used in this Form 10-Q, please see “Definitions” in our ~~2021~~2022 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
	2. Accounting Standards	7
	3. Income and Dividends per Common Share	7

	4. Revenues	7
	5. Segment Information	9
	6. Income Taxes	14
	7. Credit Losses	14
	8. Inventories	15
	9. Property, Plant and Equipment	15

	10. Asset Retirement Obligations	15
	11. Leases	16
	12. Derivatives	17
	13. Fair Value Measurements	19
	14. Debt	21
	15. Stockholders' Equity	22
	16. Incentive Based Compensation	22
	17. Defined Benefit Postretirement Plans	23
	18. Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	23
	19. Supplemental Cash Flow Information	24
	20. Equity Method Investments	24
	21. Commitments and Contingencies	25

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	2827
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	4342
Item 4.	Controls and Procedures	4342


Part II - OTHER INFORMATION
Item 1.	Legal Proceedings	4443
Item 1A.	Risk Factors	4443
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4543
Item 5.	Other Information	43
Item 6.	Exhibits	4 644
	Signatures	4745

Table of Contents

Part I – FINANCIAL INFORMATION

Item 1. Financial Statements

MARATHON OIL CORPORATION

Consolidated Statements of Income (Unaudited)


		Three Months Ended				Nine Months Ended					Three Months Ended				Nine Months Ended
		September 30,				September 30,					September 30,				September 30,
(In millions, except per share data)	(In millions, except per share data)	2022		2021		2022		2021		(In millions, except per share data)	2023		2022		2023		2022
Revenues and other income:	Revenues and other income:									Revenues and other income:
Revenues from contracts with customers	Revenues from contracts with customers	$	2,008	$	1,438	$	5,937	$	3,869	Revenues from contracts with customers	$	1,771	$	2,008	$	4,822	$	5,937
Net gain (loss) on commodity derivatives	Net gain (loss) on commodity derivatives	41		(79)		(129)		(398)		Net gain (loss) on commodity derivatives	1		41		19		(129)
Income from equity method investments	Income from equity method investments	190		86		469		179		Income from equity method investments	38		190		140		469
Net gain on disposal of assets	Net gain on disposal of assets	2		7		1		8		Net gain on disposal of assets	1		2		6		1
Other income	Other income	6		1		25		9		Other income	2		6		19		25
Total revenues and other income	Total revenues and other income	2,247		1,453		6,303		3,667		Total revenues and other income	1,813		2,247		5,006		6,303
Costs and expenses:	Costs and expenses:									Costs and expenses:
Production	Production	193		131		509		378		Production	192		193		607		509
Shipping, handling and other operating	Shipping, handling and other operating	199		219		575		538		Shipping, handling and other operating	164		199		487		575
Exploration	Exploration	73		63		92		109		Exploration	20		73		46		92
Depreciation, depletion and amortization	Depreciation, depletion and amortization	460		522		1,319		1,550		Depreciation, depletion and amortization	583		460		1,662		1,319
Impairments	Impairments	2		13		4		60		Impairments	—		2		—		4
Taxes other than income	Taxes other than income	137		88		381		236		Taxes other than income	113		137		251		381
General and administrative	General and administrative	79		70		220		227		General and administrative	72		79		225		220
Total costs and expenses	Total costs and expenses	1,143		1,106		3,100		3,098		Total costs and expenses	1,144		1,143		3,278		3,100
Income from operations	Income from operations	1,104		347		3,203		569		Income from operations	669		1,104		1,728		3,203
Net interest and other	Net interest and other	(52)		(57)		(128)		(129)		Net interest and other	(94)		(52)		(268)		(128)
Other net periodic benefit credits	Other net periodic benefit credits	5		—		14		2		Other net periodic benefit credits	5		5		11		14
Loss on early extinguishment of debt		—		(102)		—		(121)

Income before income taxes	Income before income taxes	1,057		188		3,089		321		Income before income taxes	580		1,057		1,471		3,089
Provision for income taxes	Provision for income taxes	240		4		2		24		Provision for income taxes	127		240		314		2
Net income	Net income	$	817	$	184	$	3,087	$	297	Net income	$	453	$	817	$	1,157	$	3,087
Net income per share:	Net income per share:									Net income per share:
Basic	Basic	$	1.22	$	0.23	$	4.40	$	0.38	Basic	$	0.75	$	1.22	$	1.88	$	4.40
Diluted	Diluted	$	1.22	$	0.23	$	4.39	$	0.38	Diluted	$	0.75	$	1.22	$	1.88	$	4.39
Weighted average common shares outstanding:	Weighted average common shares outstanding:									Weighted average common shares outstanding:
Basic	Basic	670		789		701		791		Basic	603		670		615		701
Diluted	Diluted	672		789		703		791		Diluted	604		672		616		703

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				Nine Months Ended					Three Months Ended				Nine Months Ended
		September 30,				September 30,					September 30,				September 30,
(In millions)	(In millions)	2022		2021		2022		2021		(In millions)	2023		2022		2023		2022
Net income	Net income	$	817	$	184	$	3,087	$	297	Net income	$	453	$	817	$	1,157	$	3,087
Other comprehensive income, net of tax
Other comprehensive income (loss), net of tax										Other comprehensive income (loss), net of tax

Change in actuarial gain (loss) and other for postretirement and postemployment plans	Change in actuarial gain (loss) and other for postretirement and postemployment plans	(3)		4		(6)		17		Change in actuarial gain (loss) and other for postretirement and postemployment plans	(4)		(3)		(17)		(6)

Change in derivative hedges unrecognized gain	Change in derivative hedges unrecognized gain	7		1		23		20		Change in derivative hedges unrecognized gain	—		7		1		23
Reclassification of de-designated forward interest rate swaps		—		—		—		(28)

Other	Other	—		—		(1)		—		Other	—		—		—		(1)
Other comprehensive income		4		5		16		9
Other comprehensive income (loss)										Other comprehensive income (loss)	(4)		4		(16)		16
Comprehensive income	Comprehensive income	$	821	$	189	$	3,103	$	306	Comprehensive income	$	449	$	821	$	1,141	$	3,103

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

Table of Contents

MARATHON OIL CORPORATION

Consolidated Balance Sheets (Unaudited)


		September 30,		December 31,			September 30,		December 31,
(In millions, except par value and share amounts)	(In millions, except par value and share amounts)	2022		2021		(In millions, except par value and share amounts)	2023		2022
Assets	Assets					Assets
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	1,109	$	580	Cash and cash equivalents	$	174	$	334
Receivables, net	Receivables, net	1,358		1,142		Receivables, net	1,434		1,146
Inventories	Inventories	103		77		Inventories	174		125
Other current assets	Other current assets	66		22		Other current assets	66		66
Total current assets	Total current assets	2,636		1,821		Total current assets	1,848		1,671
Equity method investments	Equity method investments	568		450		Equity method investments	421		577
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $23,458 and $22,412		14,245		14,499
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $25,377 and $23,876						Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $25,377 and $23,876	17,411		17,377

Deferred tax assets		155		—

Other noncurrent assets	Other noncurrent assets	254		224		Other noncurrent assets	239		315
Total assets	Total assets	$	17,858	$	16,994	Total assets	$	19,919	$	19,940
Liabilities	Liabilities					Liabilities
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	1,480	$	1,110	Accounts payable	$	1,582	$	1,279
Commercial paper						Commercial paper	450		—
Payroll and benefits payable	Payroll and benefits payable	76		74		Payroll and benefits payable	67		90
Accrued taxes	Accrued taxes	168		157		Accrued taxes	128		171
Other current liabilities	Other current liabilities	305		260		Other current liabilities	279		364
Long-term debt due within one year	Long-term debt due within one year	402		36		Long-term debt due within one year	400		402
Total current liabilities	Total current liabilities	2,431		1,637		Total current liabilities	2,906		2,306
Long-term debt	Long-term debt	3,579		3,978		Long-term debt	4,876		5,521
Deferred tax liabilities	Deferred tax liabilities	159		136		Deferred tax liabilities	386		167
Defined benefit postretirement plan obligations	Defined benefit postretirement plan obligations	117		137		Defined benefit postretirement plan obligations	94		100
Asset retirement obligations	Asset retirement obligations	283		288		Asset retirement obligations	308		295
Deferred credits and other liabilities	Deferred credits and other liabilities	102		132		Deferred credits and other liabilities	123		154
Total liabilities	Total liabilities	6,671		6,308		Total liabilities	8,693		8,543
Commitments and contingencies (Note 22)
Commitments and contingencies (Note 21)						Commitments and contingencies (Note 21)
Stockholders’ Equity	Stockholders’ Equity					Stockholders’ Equity
Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	—		—		Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	—		—
Common stock:	Common stock:					Common stock:
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at September 30, 2022 and December 31, 2021)		937		937
Held in treasury, at cost – 294 million shares and 194 million shares		(7,240)		(4,825)
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at September 30, 2023 and December 31, 2022)						Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at September 30, 2023 and December 31, 2022)	937		937
Held in treasury, at cost – 347 million shares and 304 million shares						Held in treasury, at cost – 347 million shares and 304 million shares	(8,598)		(7,512)
Additional paid-in capital	Additional paid-in capital	7,196		7,221		Additional paid-in capital	7,163		7,203
Retained earnings	Retained earnings	10,196		7,271		Retained earnings	11,634		10,663
Accumulated other comprehensive income	Accumulated other comprehensive income	98		82		Accumulated other comprehensive income	90		106
Total stockholders’ equity	Total stockholders’ equity	11,187		10,686		Total stockholders’ equity	11,226		11,397
Total liabilities and stockholders’ equity	Total liabilities and stockholders’ equity	$	17,858	$	16,994	Total liabilities and stockholders’ equity	$	19,919	$	19,940

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

Table of Contents

MARATHON OIL CORPORATION

Consolidated Statements of Cash Flows (Unaudited)


		Nine Months Ended					Nine Months Ended
		September 30,					September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
Increase (decrease) in cash and cash equivalents	Increase (decrease) in cash and cash equivalents					Increase (decrease) in cash and cash equivalents
Operating activities:	Operating activities:					Operating activities:
Net income	Net income	$	3,087	$	297	Net income	$	1,157	$	3,087
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	Depreciation, depletion and amortization	1,319		1,550		Depreciation, depletion and amortization	1,662		1,319
Impairments	Impairments	4		60		Impairments	—		4
Exploratory dry well costs and unproved property impairments	Exploratory dry well costs and unproved property impairments	85		101		Exploratory dry well costs and unproved property impairments	41		85
Net gain on disposal of assets	Net gain on disposal of assets	(1)		(8)		Net gain on disposal of assets	(6)		(1)
Loss on early extinguishment of debt		—		121

Deferred income taxes	Deferred income taxes	(137)		(32)		Deferred income taxes	264		(137)
Unrealized loss on derivative instruments, net	Unrealized loss on derivative instruments, net	4		130		Unrealized loss on derivative instruments, net	8		4

Pension and other post retirement benefits, net	Pension and other post retirement benefits, net	(28)		(25)		Pension and other post retirement benefits, net	(27)		(28)
Stock-based compensation	Stock-based compensation	28		29		Stock-based compensation	32		28
Equity method investments, net	Equity method investments, net	(130)		(57)		Equity method investments, net	99		(130)
Changes in:	Changes in:					Changes in:
Current receivables	Current receivables	(221)		(313)		Current receivables	(298)		(221)
Inventories	Inventories	(27)		(1)		Inventories	(51)		(27)
Current accounts payable and accrued liabilities	Current accounts payable and accrued liabilities	300		228		Current accounts payable and accrued liabilities	166		300
Other current assets and liabilities	Other current assets and liabilities	(57)		66		Other current assets and liabilities	(17)		(57)
All other operating, net	All other operating, net	75		(53)		All other operating, net	(23)		75
Net cash provided by operating activities	Net cash provided by operating activities	4,301		2,093		Net cash provided by operating activities	3,007		4,301
Investing activities:	Investing activities:					Investing activities:
Additions to property, plant and equipment	Additions to property, plant and equipment	(1,117)		(772)		Additions to property, plant and equipment	(1,659)		(1,117)

Acquisitions, net of cash acquired	Acquisitions, net of cash acquired	2		—		Acquisitions, net of cash acquired	(15)		2
Disposal of assets, net of cash transferred to the buyer	Disposal of assets, net of cash transferred to the buyer	8		29		Disposal of assets, net of cash transferred to the buyer	(7)		8
Equity method investments - return of capital	Equity method investments - return of capital	12		15		Equity method investments - return of capital	57		12
All other investing, net		—		—

Net cash used in investing activities	Net cash used in investing activities	(1,095)		(728)		Net cash used in investing activities	(1,624)		(1,095)
Financing activities:	Financing activities:					Financing activities:
Proceeds from revolving credit facility						Proceeds from revolving credit facility	1,018		—
Repayments of revolving credit facility						Repayments of revolving credit facility	(1,468)		—
Proceeds from commercial paper borrowings, net						Proceeds from commercial paper borrowings, net	450		—
Borrowings						Borrowings	200		—
Debt repayments						Debt repayments	(401)		(35)

Debt repayment		(35)		(1,400)
Debt extinguishment costs		—		(117)
Shares repurchased under buyback programs	Shares repurchased under buyback programs	(2,474)		—		Shares repurchased under buyback programs	(1,121)		(2,474)
Dividends paid	Dividends paid	(162)		(94)		Dividends paid	(186)		(162)
Purchases of shares for tax withholding obligations	Purchases of shares for tax withholding obligations	(21)		(10)		Purchases of shares for tax withholding obligations	(31)		(21)
All other financing, net	All other financing, net	15		(1)		All other financing, net	(4)		15
Net cash used in financing activities	Net cash used in financing activities	(2,677)		(1,622)		Net cash used in financing activities	(1,543)		(2,677)

Net increase (decrease) in cash and cash equivalents	Net increase (decrease) in cash and cash equivalents	529		(257)		Net increase (decrease) in cash and cash equivalents	(160)		529
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	580		742		Cash and cash equivalents at beginning of period	334		580
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	1,109	$	485	Cash and cash equivalents at end of period	$	174	$	1,109

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

Table of Contents

MARATHON OIL CORPORATION

Consolidated Statements of Stockholders’ Equity (Unaudited)


		Total Equity of Marathon Oil Stockholders															Total Equity of Marathon Oil Stockholders
(In millions)	(In millions)	Preferred Stock		Common Stock		Treasury Stock		Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total Equity		(In millions)	Preferred Stock		Common Stock		Treasury Stock		Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total Equity
Nine Months Ended September 30, 2021
December 31, 2020 Balance		$	—	$	937	$	(4,089)	$	7,174	$	6,466	$	73	$	10,561

Stock-based compensation		—		—		(24)		21		—		—		(3)
Net income		—		—		—		—		97		—		97
Other comprehensive income		—		—		—		—		—		39		39
Dividends paid (per share amount of $0.03)		—		—		—		—		(23)		—		(23)
March 31, 2021 Balance		$	—	$	937	$	(4,113)	$	7,195	$	6,540	$	112	$	10,671

Stock-based compensation		—		—		8		6		—		—		14
Net income		—		—		—		—		16		—		16
Other comprehensive loss		—		—		—		—		—		(35)		(35)
Dividends paid (per share amount of $0.04)		—		—		—		—		(32)		—		(32)
June 30, 2021 Balance		$	—	$	937	$	(4,105)	$	7,201	$	6,524	$	77	$	10,634

Stock-based compensation		—		—		—		12		—		—		12
Net income		—		—		—		—		184		—		184
Other comprehensive income		—		—		—		—		—		5		5
Dividends paid (per share amount of $0.05)		—		—		—		—		(39)		—		(39)
September 30, 2021 Balance		$	—	$	937	$	(4,105)	$	7,213	$	6,669	$	82	$	10,796

Nine Months Ended September 30, 2022	Nine Months Ended September 30, 2022															Nine Months Ended September 30, 2022
December 31, 2021 Balance	December 31, 2021 Balance	$	—	$	937	$	(4,825)	$	7,221	$	7,271	$	82	$	10,686	December 31, 2021 Balance	$	—	$	937	$	(4,825)	$	7,221	$	7,271	$	82	$	10,686
Shares repurchased under buyback programs	Shares repurchased under buyback programs	—		—		(592)		—		—		—		(592)		Shares repurchased under buyback programs	—		—		(592)		—		—		—		(592)
Stock-based compensation	Stock-based compensation	—		—		55		(43)		—		—		12		Stock-based compensation	—		—		55		(43)		—		—		12
Net income	Net income	—		—		—		—		1,304		—		1,304		Net income	—		—		—		—		1,304		—		1,304
Other comprehensive income	Other comprehensive income	—		—		—		—		—		8		8		Other comprehensive income	—		—		—		—		—		8		8
Dividends paid (per share amount of $0.07)	Dividends paid (per share amount of $0.07)	—		—		—		—		(52)		—		(52)		Dividends paid (per share amount of $0.07)	—		—		—		—		(52)		—		(52)
March 31, 2022 Balance	March 31, 2022 Balance	$	—	$	937	$	(5,362)	$	7,178	$	8,523	$	90	$	11,366	March 31, 2022 Balance	$	—	$	937	$	(5,362)	$	7,178	$	8,523	$	90	$	11,366
Shares repurchased under buyback programs	Shares repurchased under buyback programs	—		—		(760)		—		—		—		(760)		Shares repurchased under buyback programs	—		—		(760)		—		—		—		(760)
Stock-based compensation	Stock-based compensation	—		—		4		8		—		—		12		Stock-based compensation	—		—		4		8		—		—		12
Net income	Net income	—		—		—		—		966		—		966		Net income	—		—		—		—		966		—		966
Other comprehensive income	Other comprehensive income	—		—		—		—		—		4		4		Other comprehensive income	—		—		—		—		—		4		4
Dividends paid (per share amount of $0.08)	Dividends paid (per share amount of $0.08)	—		—		—		—		(56)		—		(56)		Dividends paid (per share amount of $0.08)	—		—		—		—		(56)		—		(56)
June 30, 2022 Balance	June 30, 2022 Balance	$	—	$	937	$	(6,118)	$	7,186	$	9,433	$	94	$	11,532	June 30, 2022 Balance	$	—	$	937	$	(6,118)	$	7,186	$	9,433	$	94	$	11,532
Shares repurchased under buyback programs	Shares repurchased under buyback programs	—		—		(1,122)		—		—		—		(1,122)		Shares repurchased under buyback programs	—		—		(1,122)		—		—		—		(1,122)
Stock-based compensation	Stock-based compensation	—		—		—		10		—		—		10		Stock-based compensation	—		—		—		10		—		—		10
Net income	Net income	—		—		—		—		817		—		817		Net income	—		—		—		—		817		—		817
Other comprehensive income	Other comprehensive income	—		—		—		—		—		4		4		Other comprehensive income	—		—		—		—		—		4		4
Dividends paid (per share amount of $0.08)	Dividends paid (per share amount of $0.08)	—		—		—		—		(54)		—		(54)		Dividends paid (per share amount of $0.08)	—		—		—		—		(54)		—		(54)
September 30, 2022 Balance	September 30, 2022 Balance	$	—	$	937	$	(7,240)	$	7,196	$	10,196	$	98	$	11,187	September 30, 2022 Balance	$	—	$	937	$	(7,240)	$	7,196	$	10,196	$	98	$	11,187

Nine Months Ended September 30, 2023																Nine Months Ended September 30, 2023
December 31, 2022 Balance																December 31, 2022 Balance	$	—	$	937	$	(7,512)	$	7,203	$	10,663	$	106	$	11,397
Shares repurchased under buyback programs																Shares repurchased under buyback programs	—		—		(334)		—		—		—		(334)
Excise tax on shares repurchased																Excise tax on shares repurchased	—		—		(3)		—		—		—		(3)
Stock-based compensation																Stock-based compensation	—		—		35		(54)		—		—		(19)
Net income																Net income	—		—		—		—		417		—		417
Other comprehensive loss																Other comprehensive loss	—		—		—		—		—		(7)		(7)
Dividends paid (per share amount of $0.10)																Dividends paid (per share amount of $0.10)	—		—		—		—		(63)		—		(63)
March 31, 2023 Balance																March 31, 2023 Balance	$	—	$	937	$	(7,814)	$	7,149	$	11,017	$	99	$	11,388
Shares repurchased under buyback programs																Shares repurchased under buyback programs	—		—		(372)		—		—		—		(372)
Excise tax on shares repurchased																Excise tax on shares repurchased	—		—		(3)		—		—		—		(3)
Stock-based compensation																Stock-based compensation	—		—		1		10		—		—		11
Net income																Net income	—		—		—		—		287		—		287
Other comprehensive loss																Other comprehensive loss	—		—		—		—		—		(5)		(5)
Dividends paid (per share amount of $0.10)																Dividends paid (per share amount of $0.10)	—		—		—		—		(62)		—		(62)
June 30, 2023 Balance																June 30, 2023 Balance	$	—	$	937	$	(8,188)	$	7,159	$	11,242	$	94	$	11,244
Shares repurchased under buyback programs																Shares repurchased under buyback programs	—		—		(415)		—		—		—		(415)
Excise tax on shares repurchased																Excise tax on shares repurchased	—		—		(4)		—		—		—		(4)
Stock-based compensation																Stock-based compensation	—		—		9		4		—		—		13
Net income																Net income	—		—		—		—		453		—		453
Other comprehensive loss																Other comprehensive loss	—		—		—		—		—		(4)		(4)
Dividends paid (per share amount of $0.10)																Dividends paid (per share amount of $0.10)	—		—		—		—		(61)		—		(61)
September 30, 2023 Balance																September 30, 2023 Balance	$	—	$	937	$	(8,598)	$	7,163	$	11,634	$	90	$	11,226

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

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

1. Basis of Presentation

These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements.

These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our ~~2021~~2022 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of ~~2022~~2023 are not necessarily indicative of the results to be expected for the full year.

2. Accounting Standards

Accounting Standards Updates Adopted

No accounting standards were adopted in the third quarter ~~or first nine months~~ of ~~2022~~2023 that had a material impact on our consolidated financial statements.

Accounting Standards Updates Not Yet Adopted

~~In March 2020, the FASB~~There were no issued ASU 2020-04, which provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions that reference London Interbank Offered Rate (LIBOR) or another reference ratebut pending accounting standards expected to ~~be discontinued. The guidance is effective March 12, 2020 and can be applied prospectively through December 31, 2022. Upon adoption, we do not believe it will~~ have a material impact on our consolidated ~~results of operations,~~ financial ~~position and cash flows.~~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 1 million of antidilutive stock options and performance units for the three and nine months ended September 30, 2023, and 1 million and 2 million of antidilutive stock options and performance units for the three and nine months ended September 30, 2022, ~~respectively, and 4 million of stock options for each of the three and nine months ended September 30, 2021, that were antidilutive.~~respectively.


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	(In millions, except per share data)	2022		2021		2022		2021		(In millions, except per share data)	2023		2022		2023		2022
Net income	Net income	$	817	$	184	$	3,087	$	297	Net income	$	453	$	817	$	1,157	$	3,087

Weighted average common shares outstanding	Weighted average common shares outstanding	670		789		701		791		Weighted average common shares outstanding	603		670		615		701
Effect of dilutive securities	Effect of dilutive securities	2		—		2		—		Effect of dilutive securities	1		2		1		2
Weighted average common shares, diluted	Weighted average common shares, diluted	672		789		703		791		Weighted average common shares, diluted	604		672		616		703
Net income per share:	Net income per share:									Net income per share:
Basic	Basic	$	1.22	$	0.23	$	4.40	$	0.38	Basic	$	0.75	$	1.22	$	1.88	$	4.40
Diluted	Diluted	$	1.22	$	0.23	$	4.39	$	0.38	Diluted	$	0.75	$	1.22	$	1.88	$	4.39

Dividends per share	Dividends per share	$	0.08	$	0.05	$	0.23	$	0.12	Dividends per share	$	0.10	$	0.08	$	0.30	$	0.23

4. Revenues

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

As of September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, receivables from contracts with customers, included in receivables, ~~net~~less reserves for credit losses, were $1.1 billion and ~~$961~~$875 million, respectively.

Table of Contents

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 nine months ended September 30:

United States


	Three Months Ended September 30, 2023
(In millions)	Eagle Ford		Bakken		Oklahoma		Permian		Other U.S.		Total
Crude oil and condensate	$	587	$	580	$	64	$	164	$	13	$	1,408
Natural gas liquids	80		47		30		20		—		177
Natural gas	48		20		31		12		1		112
Other	2		—		—		—		1		3
Revenues from contracts with customers	$	717	$	647	$	125	$	196	$	15	$	1,700


		Three Months Ended September 30, 2022													Three Months Ended September 30, 2022
(In millions)	(In millions)	Eagle Ford		Bakken		Oklahoma		Northern Delaware		Other U.S.		Total		(In millions)	Eagle Ford		Bakken		Oklahoma		Permian		Other U.S.		Total
Crude oil and condensate	Crude oil and condensate	$	523	$	648	$	104	$	114	$	39	$	1,428	Crude oil and condensate	$	523	$	648	$	104	$	114	$	39	$	1,428
Natural gas liquids	Natural gas liquids	49		82		63		16		6		216		Natural gas liquids	49		82		63		16		6		216
Natural gas	Natural gas	56		67		105		22		11		261		Natural gas	56		67		105		22		11		261
Other	Other	3		—		—		—		19		22		Other	3		—		—		—		19		22
Revenues from contracts with customers	Revenues from contracts with customers	$	631	$	797	$	272	$	152	$	75	$	1,927	Revenues from contracts with customers	$	631	$	797	$	272	$	152	$	75	$	1,927


		Three Months Ended September 30, 2021													Nine Months Ended September 30, 2023
(In millions)	(In millions)	Eagle Ford		Bakken		Oklahoma		Northern Delaware		Other U.S.		Total		(In millions)	Eagle Ford		Bakken		Oklahoma		Permian		Other U.S.		Total
Crude oil and condensate	Crude oil and condensate	$	391	$	425	$	74	$	75	$	19	$	984	Crude oil and condensate	$	1,606	$	1,467	$	205	$	475	$	35	$	3,788
Natural gas liquids	Natural gas liquids	50		63		53		12		5		183		Natural gas liquids	215		125		102		60		—		502
Natural gas	Natural gas	38		29		62		12		3		144		Natural gas	141		69		95		30		2		337
Other	Other	2		—		—		—		62		64		Other	5		—		—		—		11		16
Revenues from contracts with customers	Revenues from contracts with customers	$	481	$	517	$	189	$	99	$	89	$	1,375	Revenues from contracts with customers	$	1,967	$	1,661	$	402	$	565	$	48	$	4,643

Nine Months Ended September 30, 2022
(In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total
Crude oil and condensate $ 1,526 $ 2,049 $ 341 $ 302 $ 124 $ 4,342
Natural gas liquids 148 263 191 46 23 671
Natural gas 145 156 256 55 28 640
Other 6 — — — 71 77
Revenues from contracts with customers $ 1,825 $ 2,468 $ 788 $ 403 $ 246 $ 5,730


		Nine Months Ended September 30, 2021													Nine Months Ended September 30, 2022
(In millions)	(In millions)	Eagle Ford		Bakken		Oklahoma		Northern Delaware		Other U.S.		Total		(In millions)	Eagle Ford		Bakken		Oklahoma		Permian		Other U.S.		Total
Crude oil and condensate	Crude oil and condensate	$	1,003	$	1,208	$	206	$	229	$	65	$	2,711	Crude oil and condensate	$	1,526	$	2,049	$	341	$	302	$	124	$	4,342
Natural gas liquids	Natural gas liquids	109		152		127		32		10		430		Natural gas liquids	148		263		191		46		23		671
Natural gas	Natural gas	114		71		212		42		11		450		Natural gas	145		156		256		55		28		640
Other	Other	6		—		—		—		99		105		Other	6		—		—		—		71		77
Revenues from contracts with customers	Revenues from contracts with customers	$	1,232	$	1,431	$	545	$	303	$	185	$	3,696	Revenues from contracts with customers	$	1,825	$	2,468	$	788	$	403	$	246	$	5,730

~~International (E.G.)~~

Three Months Ended September 30, Nine Months Ended September 30,
(In millions) 2022 2021 2022 2021
Crude oil and condensate $ 75 $ 56 $ 186 $ 151
Natural gas liquids 1 — 2 2
Natural gas 5 6 17 18
Other — 1 2 2
Revenues from contracts with customers $ 81 $ 63 $ 207 $ 173

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

International (E.G.)


	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2023		2022		2023		2022
Crude oil and condensate	$	64	$	75	$	160	$	186
Natural gas liquids	1		1		2		2
Natural gas	5		5		14		17
Other	1		—		3		2
Revenues from contracts with customers	$	71	$	81	$	179	$	207

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~~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.”)

Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs are not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, ~~goodwill and equity method investments,~~dry wells, changes in our valuation allowance, unrealized gains or losses on commodity and interest rate derivative instruments, effects of pension settlements and curtailments, expensed transaction costs for business combinations or other items (as determined by the chief operating decision maker (“CODM”)) are not allocated to operating segments.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	Three Months Ended September 30, 2023
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,700	$	71	$	—		$	1,771
Net gain (loss) on commodity derivatives	7		—		(6)		(b)	1
Income from equity method investments	—		38		—			38
Net gain on disposal of assets	—		—		1			1
Other income	—		1		1			2
Less costs and expenses:
Production	173		19		—			192
Shipping, handling and other operating	162		2		—			164
Exploration	8		1		11		(c)	20
Depreciation, depletion and amortization	570		12		1			583

Taxes other than income	112		—		1			113
General and administrative	32		3		37			72
Net interest and other	—		—		94			94
Other net periodic benefit costs	—		—		(5)			(5)

Income tax provision (benefit)	145		11		(29)			127
Segment income (loss)	$	505	$	62	$	(114)		$	453
Total assets	$	18,503	$	1,072	$	344		$	19,919
Capital expenditures(a)	$	444	$	1	$	4		$	449

(a)Includes accruals and excludes acquisitions.

(b)Unrealized loss on commodity derivative instruments (See Note 12).

(c)Includes $11 million of unproved impairments related to Permian exploration leases.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	Three Months Ended September 30, 2022
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	1,927	$	81	$	—		$	2,008
Net gain (loss) on commodity derivatives	(26)		—		67		(b)	41
Income from equity method investments	—		190		—			190
Net gain on disposal of assets	—		—		2			2
Other income	4		1		1			6
Less costs and expenses:
Production	173		20		—			193
Shipping, handling and other operating	171		5		23			199
Exploration	11		—		62		(c)	73
Depreciation, depletion and amortization	441		14		5			460
Impairments	—		—		2			2
Taxes other than income	136		—		1			137
General and administrative	37		4		38			79
Net interest and other	—		—		52			52
Other net periodic benefit costs	—		—		(5)			(5)

Income tax provision (benefit)	213		48		(21)			240
Segment income (loss)	$	723	$	181	$	(87)		$	817
Total assets	$	15,487	$	1,294	$	1,077		$	17,858
Capital expenditures(a)	$	406	$	1	$	6		$	413

(a)Includes ~~accruals.~~accruals and excludes acquisitions.

(b)Unrealized gain on commodity derivative instruments (See Note 1312).

(c)Includes dry well costs and unproved property impairments of $48 million for Louisiana Austin Chalk exploration leases and $14 million for Permian ~~exploration leases (See~~ ~~Note 9and~~ ~~Note 10~~).

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

Three Months Ended September 30, 2021
(In millions) U.S. Int’l Not Allocated to Segments Total
Revenues from contracts with customers $ 1,375 $ 63 $ — $ 1,438
Net gain (loss) on commodity derivatives (106) — 27 (b) (79)
Income from equity method investments — 86 — 86
Net gain on disposal of assets — — 7 7
Other income — — 1 1
Less costs and expenses:
Production 119 12 — 131
Shipping, handling and other operating 209 7 3 219
Exploration 15 — 48 (c) 63
Depreciation, depletion and amortization 499 17 6 522
Impairments — — 13 (d) 13
Taxes other than income 88 — — 88
General and administrative 29 3 38

70
Net interest and other — — 57 (e) 57
Other net periodic benefit costs — — — —
Loss on early extinguishment of debt — — 102 (f) 102
Income tax provision (benefit) 5 17 (18) 4
Segment income (loss) $ 305 $ 93 $ (214) $ 184
Total assets $ 15,528 $ 1,071 $ 562 $ 17,161
Capital expenditures(a)
$ 303 $ 2 $ 3 $ 308

~~(a)Includes accruals.~~

~~(b)Unrealized gain on commodity derivative instruments (See~~ ~~Note 13~~).

~~(c)Includes~~ unproved property impairments of $20 million for Louisiana exploration leases and$16 million related to the disposition of a Permian lease. Also includes $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian.

~~(d)Includes impairments of $5 million for proved properties in Permian (SeeNote 10) and $8 million associated with decommissioning costs for non-producing long-lived assets in GOM (SeeNote 1~~0~~and~~ ~~Note 11~~).

~~(e)Includes a $5 million gain on 2022 interest rate swaps and a $3 million gain on 2025 interest rate swaps (See~~ ~~Note 13~~).

~~(f)Represents costs related to a make-whole provision premium and the write off of issuance costs related to the redemption of the 2025 Notes in September 2021 (See~~ ~~Note 15~~).leases.

1011

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

Nine Months Ended September 30, 2022
(In millions) U.S. Int’l Not Allocated to Segments Total
Revenues from contracts with customers $ 5,730 $ 207 $ — $ 5,937
Net loss on commodity derivatives (125) — (4) (b) (129)
Income from equity method investments — 469 — 469
Net gain on disposal of assets — — 1 1
Other income 10 5 10 25
Less costs and expenses:
Production 464 45 — 509
Shipping, handling and other operating 508 15 52 575
Exploration 30 — 62 (c) 92
Depreciation, depletion and amortization 1,260 45 14 1,319
Impairments — — 4

4
Taxes other than income 374 — 7 381
General and administrative 94 10 116

220
Net interest and other — — 128 (d) 128
Other net periodic benefit costs — — (14) (14)
Income tax provision (benefit) 655 110 (763) (e) 2
Segment income $ 2,230 $ 456 $ 401 $ 3,087
Total assets $ 15,487 $ 1,294 $ 1,077 $ 17,858
Capital expenditures(a)
$ 1,124 $ 1 $ 11 $ 1,136


	Nine Months Ended September 30, 2023
(In millions)	U.S.			Int’l		Not Allocated to Segments			Total
Revenues from contracts with customers	$	4,643		$	179	$	—		$	4,822
Net gain (loss) on commodity derivatives	27			—		(8)		(c)	19
Income from equity method investments	—			140		—			140
Net gain on disposal of assets	—			—		6			6
Other income	12			5		2			19
Less costs and expenses:
Production	542			65		—			607
Shipping, handling and other operating	482			5		—			487
Exploration	19			1		26		(d)	46
Depreciation, depletion and amortization	1,622			34		6			1,662

Taxes other than income	252		(b)	—		(1)			251
General and administrative	98			9		118			225
Net interest and other	—			—		268			268
Other net periodic benefit costs	—			—		(11)			(11)

Income tax provision (benefit)	372			29		(87)			314
Segment income (loss)	$	1,295		$	181	$	(319)		$	1,157
Total assets	$	18,503		$	1,072	$	344		$	19,919
Capital expenditures(a)	$	1,661		$	3	$	9		$	1,673

(a)Includes ~~accruals.~~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 (SeeNo te 12).

(d)Includes$10 million of dry well expense associated with wells in Permian (See Note 9) and $11 million of unproved impairments related to Permian exploration leases.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	Nine Months Ended September 30, 2022
(In millions)	U.S.		Int’l		Not Allocated to Segments			Total
Revenue from contracts with customers	$	5,730	$	207	$	—		$	5,937
Net loss on commodity derivatives	(125)		—		(4)		(b)	(129)
Income from equity method investments	—		469		—			469
Net gain on disposal of assets	—		—		1			1
Other income	10		5		10			25
Less costs and expenses:
Production	464		45		—			509
Shipping, handling and other operating	508		15		52			575
Exploration	30		—		62		(c)	92
Depreciation, depletion and amortization	1,260		45		14			1,319
Impairments	—		—		4			4
Taxes other than income	374		—		7			381
General and administrative	94		10		116			220
Net interest and other	—		—		128		(d)	128
Other net periodic benefit credit	—		—		(14)			(14)

Income tax provision (benefit)	655		110		(763)		(e)	2
Segment income	$	2,230	$	456	$	401		$	3,087
Total assets	$	15,487	$	1,294	$	1,077		$	17,858
Capital expenditures(a)	$	1,124	$	1	$	11		$	1,136

(a)Includes accruals and excludes acquisitions.

(b)Unrealized loss on commodity derivative instruments (See Note 1123).

(c)Includes dry well costs and unproved property impairments of $48 million for Louisiana exploration leases and $14 million for Permian exploration ~~leases (See~~ ~~Note 9andNote 10~~).leases.

(d)Includes a $17 million gain on 2025 interest rate swaps (See Note 1312).

(e)Includes a $685 million benefit related to the partial release of our valuation allowance (See Note 6).

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

Nine Months Ended September 30, 2021
(In millions) U.S. Int’l Not Allocated to Segments Total
Revenue from contracts with customers $ 3,696 $ 173 $ — $ 3,869
Net loss on commodity derivatives (268) — (130) (b) (398)
Income from equity method investments — 179 —

179
Net gain on disposal of assets — — 8 8
Other income 4 3 2 9
Less costs and expenses:
Production 343 35 — 378
Shipping, handling and other operating 506 13 19 538
Exploration 54 — 55 (c) 109
Depreciation, depletion and amortization 1,477 54 19 1,550
Impairments — — 60 (d) 60
Taxes other than income 238 — (2) 236
General and administrative 79 9 139 (e) 227
Net interest and other — — 129 (f) 129
Other net periodic benefit credit — — (2)

(2)
Loss on early extinguishment of debt — — 121 (g) 121
Income tax provision (benefit) 11 33 (20) 24
Segment income (loss) $ 724 $ 211 $ (638) $ 297
Total assets $ 15,528 $ 1,071 $ 562 $ 17,161
Capital expenditures(a)
$ 770 $ 4 $ 7 $ 781

~~(a)Includes accruals.~~

~~(b)Unrealized loss on commodity derivative instruments (SeeNote 1~~3).

~~(c)~~Includes unproved property impairments of $20 million for Louisiana exploration leases and $16 million related to the disposition of a lease in Permian. Also includes $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian.

~~(d)Includes impairments of $24 million for central facilities in Eagle Ford (SeeNote 10), $5 million for proved properties in Permian (SeeNote 10), and $30 million associated with decommissioning costs for non-producing long-lived assets in GOM (SeeNote 10and~~ ~~Note 11~~).

~~(e)Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction.~~

~~(f)Includes a $24 million gain on 2022 interest rate swaps and a $34 million gain on 2025 interest rate swaps (See~~ ~~Note 13~~).

~~(g)~~Represents costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs in regards to the redemption of the 2022 Notes in April 2021 and 2025 Notes in September 2021 (See ~~Note 15~~).

~~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 nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, our effective income tax rates were as follows:

Three Months Ended September 30, Nine Months Ended September 30,
2022 2021 2022 2021
Effective income tax rate 23 % 2 % — % 7 %


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Effective income tax rate	22	%	23	%	21	%	—	%

•2022 — Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the nine months ended September 30, 2022, due to the first quarter 2022 release of the valuation allowance on certain U.S. and state deferred tax assets resulting in a non-cash deferred tax benefit of $685 million. As we previously disclosed in our 2021 Form 10-K, we maintained a full valuation allowance on our net federal deferred tax assets and would continue to do so until there exists sufficient positive evidence to support a reversal of the allowance. In the first quarter, as a result of significant increases in commodity prices, corresponding increases in projections of our future taxable income, and the absence of objective negative evidence such as a cumulative loss in recent years, we determined we have sufficient positive evidence to release a majority of the federal valuation allowance. We retained a partial valuation allowance on certain U.S. deferred tax assets primarily as a result of volatility in commodity prices impacting assessed likelihood of future realizability.

•~~2021~~— Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the three and nine months ended September 30, 2021, as a result of the valuation allowance on net federal deferred tax assets in the U.S. which was in place at the time. In ~~addition, the income mix of our U.S. and E.G. operations, including the income mix within E.G. between equity method investees and subsidiaries, contributed to the difference.~~

On August ~~16,~~ 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 ~~created and extended certain tax-related energy incentives. The~~guidance, we do not anticipate being subject to the corporate book minimum tax ~~provisions of the IRA which may apply to us are generally effective~~ in 2023 ~~or later and therefore~~but anticipate that the corporate book minimum tax ~~impacts to us~~will apply in ~~2022 are~~2024. The U.S. Treasury is expected to publish further guidance and regulations that will be ~~immaterial. We~~relevant to scoping considerations and the calculation of minimum income tax liabilities. As this guidance is issued, we will continue to ~~monitor~~evaluate and assess the impact ~~that~~ the IRA may have on our ~~U.S.~~current and future period income taxes. We have made an accounting policy election to consider the effects of the corporate book minimum tax ~~liability for 2023 or later years.~~on the realizability of our deferred tax assets, carryforwards and tax credits as a period cost when they arise.

7. Credit Losses

The majority of our receivables are from purchasers of commodities or joint interest owners in properties we operate, both of which are recorded at estimated or invoiced amounts and do not bear interest. The majority of these receivables have payment terms of 30 days or less. At the end of each reporting period, we assess the collectability of our receivables and estimate the expected credit losses using historical data, current market conditions, reasonable and supportable forecasts of future economic conditions and other data as deemed appropriate.

Changes in the allowance for credit losses were as follows:


(In millions)	(In millions)	September 30, 2022		December 31, 2021		(In millions)	September 30, 2023		December 31, 2022
Beginning balance as of January 1	Beginning balance as of January 1	$	15	$	22	Beginning balance as of January 1	$	10	$	15

Current period provision	Current period provision	(2)		3		Current period provision	3		(3)
Current period write offs	Current period write offs	(1)		(5)		Current period write offs	(2)		(2)
Recoveries of amounts previously reserved	Recoveries of amounts previously reserved	—		(5)		Recoveries of amounts previously reserved	(1)		—
Ending balance	Ending balance	$	12	$	15	Ending balance	$	10	$	10

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

8. Inventories

Crude oil and natural gas liquids are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment which are valued at weighted average cost and reviewed periodically for obsolescence or impairment when market conditions indicate.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~


(In millions)	(In millions)	September 30, 2022		December 31, 2021		(In millions)	September 30, 2023		December 31, 2022
Crude oil and natural gas liquids	Crude oil and natural gas liquids	$	14	$	8	Crude oil and natural gas liquids	$	9	$	15
Supplies and other items	Supplies and other items	89		69		Supplies and other items	165		110
Inventories	Inventories	$	103	$	77	Inventories	$	174	$	125

9. Property, Plant and Equipment


(In millions)	(In millions)	September 30, 2022		December 31, 2021		(In millions)	September 30, 2023		December 31, 2022
United States	United States	$	13,889	$	14,097	United States	$	17,098	$	17,034
International	International	302		347		International	260		288
Corporate	Corporate	54		55		Corporate	53		55
Net property, plant and equipment	Net property, plant and equipment	$	14,245	$	14,499	Net property, plant and equipment	$	17,411	$	17,377

As of September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, we had $10 million and $20 million, ~~and~~ ~~$80 million~~, respectively, of e~~xploratory~~exploratory well costs capitalized greater than one year related to suspended wells. Management believes these wells exhibit sufficient quantities of hydrocarbons to justify potential development. ~~The majority~~All of the suspended wells require completion activities ~~and installation of infrastructure~~ in order to classify the reserves as proved. The decrease during the nine months ended September 30, ~~2022~~2023 included a ~~$46 million~~ reduction in suspended well costs as we ~~resumed drilling or completion activities and brought previously suspended wells to sales. During the third quarter of 2022, we also~~ recorded ~~$14~~ $10 million of ~~dry~~dry well ~~costs~~expense associated with drilled and uncompleted exploratory wells ~~primarily~~ in ~~Louisiana Austin Chalk. See~~ ~~Note 10~~ ~~for further information.~~Permian.

10. ~~Impairments~~

~~The following table summarizes impairment charges of proved properties and their corresponding fair values.~~

Three Months Ended September 30,
2022 2021
(In millions) Fair Value Impairment Fair Value Impairment
Long-lived assets held for use $ — $ — $ — $ 5
Asset retirement costs of long-lived assets $ — $ 2 $ — $ 8

Nine Months Ended September 30,
2022 2021
(In millions) Fair Value Impairment Fair Value Impairment
Long-lived assets held for use $ — $ — $ — $ 30
Asset retirement costs of long-lived assets $ — $ 4 $ — $ 30

•~~2022~~— ~~There were no significant impairments of proved property in 2022.~~

During the third quarter of 2022, we recognized impairments totaling $48 million of unproved property leases and dry well costs in Louisiana Austin Chalk. The impairments resulted from a combination of factors including timing of lease expiration dates, our assessment of risk and resource, and the decision not to develop the acreage. We also recognized impairments of $14 million for unproved property leases in Permian as a result of an acreage exchange. The combined effects of these impairments were recorded as exploration expense.

•~~2021~~— During the third quarter of 2021, we recognized unproved property impairments of $20 million for Louisiana exploration leases and $16 million related to the disposition of a Permian lease. In addition, we also recognized $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. The combined effects of these impairments were recorded as exploration expense.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~For proved property, during the third quarter of 2021, we recorded an impairment expense of $5 million associated with our interests in outside operated conventional assets located in New Mexico.~~

~~In the second quarter of 2021, we recorded an impairment expense of $24 million associated with the decommissioning of two central facilities located in Eagle Ford.~~

During the nine months ended September 30, 2021, we recognized an incremental $30 million of impairment expense associated with an increase in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico. See ~~Note 11~~ ~~for further information.~~

~~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:


		September 30,					September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
Beginning balance as of January 1	Beginning balance as of January 1	$	316	$	254	Beginning balance as of January 1	$	340	$	316
Incurred liabilities, including acquisitions	Incurred liabilities, including acquisitions	10		9		Incurred liabilities, including acquisitions	4		10
Settled liabilities, including dispositions	Settled liabilities, including dispositions	(8)		(3)		Settled liabilities, including dispositions	(27)		(8)
Accretion expense (included in depreciation, depletion and amortization)	Accretion expense (included in depreciation, depletion and amortization)	11		9		Accretion expense (included in depreciation, depletion and amortization)	11		11
Revisions of estimates	Revisions of estimates	(1)		40		Revisions of estimates	12		(1)

Ending balance as of September 30, total	Ending balance as of September 30, total	$	328	$	309	Ending balance as of September 30, total	$	340	$	328

Ending balance as of September 30, short-term	Ending balance as of September 30, short-term	$	45	$	23	Ending balance as of September 30, short-term	$	32	$	45

Table of Contents

•
~~2021~~— ~~In the first nine months of 2021, we had revisions of estimates totaling $37 million related~~

MARATHON OIL CORPORATION

Notes to anticipated costs for decommissioning certain wells, pipelines and production facilities for previously divested offshore non-producing long-lived assets located in the Gulf of Mexico. As of September 30, 2021, $14 million of these Gulf of Mexico related revisions of estimates were classified as short-term. See Consolidated Financial Statements (Unaudited)

~~Note 22~~ ~~for further information. Of the $37 million, approximately $30 million was recognized as impairment expense during the nine months ended September 30, 2021. See~~ ~~Note 10~~ ~~for further information.~~

~~12.~~11. Leases

Lessee

Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows:

(In millions) Balance Sheet Location: September 30, 2022 December 31, 2021
ROU assets:
Operating leases Other noncurrent assets $ 95 $ 59
Finance leases Other noncurrent assets 26 28
Total ROU assets $ 121 $ 87
Lease liabilities:
Current liabilities
Operating leases Other current liabilities $ 65 $ 40
Finance leases Other current liabilities 6 6
Noncurrent liabilities
Operating leases Deferred credits and other liabilities 35 23
Finance leases Deferred credits and other liabilities 19 24
Total lease liabilities $ 125 $ 93

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~


(In millions)	Balance Sheet Location:	September 30, 2023		December 31, 2022
ROU assets:
Operating leases	Other noncurrent assets	$	93	$	123
Finance leases	Other noncurrent assets	20		24
Total ROU assets		$	113	$	147
Lease liabilities:
Current liabilities
Operating leases	Other current liabilities	$	63	$	94
Finance leases	Other current liabilities	7		6
Noncurrent liabilities
Operating leases	Deferred credits and other liabilities	35		32
Finance leases	Deferred credits and other liabilities	13		18
Total lease liabilities		$	118	$	150

Operating Leases

We enter into various lease agreements to support our operations including drilling rigs, ~~well fracturing equipment,~~ compressors, buildings, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and the majority of our existing leases are classified as either short-term or long-term operating leases.

Finance Leases

In 2018, we signed an agreement with an owner/lessor to construct and lease a new build-to-suit office building in Houston, Texas. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In March 2022, we made our first cash lease payment. ~~For~~During the nine months ended September 30, 2023 and 2022, ~~our~~we have made cash lease payments ~~were~~totaling approximately $16 million and $6 ~~million.~~million, respectively. At the end of the initial lease term, we can negotiate to extend the lease term for an additional five years, subject to the approval of the participants; purchase the property subject to certain terms and conditions; or remarket the property to an unrelated third party. The lease contains a residual value guarantee of 100% of the total acquisition and construction costs.

Lessor

Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in E.G., which is occupied by EGHoldings, a related party equity method investee – see Note 2120. The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below.


(In millions)	(In millions)	Operating Lease Future Cash Receipts		(In millions)	Operating Lease Future Cash Receipts
2022		$	2
2023	2023	6		2023	$	2
2024	2024	6		2024	6
2025	2025	6		2025	6
2026	2026	6		2026	6
2027				2027	6
Thereafter	Thereafter	48		Thereafter	42
Total undiscounted cash flows	Total undiscounted cash flows	$	74	Total undiscounted cash flows	$	68

~~13.~~

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

12. Derivatives

We may use derivatives to manage a portion of our exposure to commodity price risk, commodity locational risk and interest rate risk. For further information regarding the fair value measurement of derivative instruments, see Note 1413. All of our commodity derivatives and interest rate derivatives are subject to enforceable master netting arrangements or similar agreements under which we report net amounts.

The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with ~~where they appear on the~~their locations in our consolidated balance sheets.


		September 30, 2022								September 30, 2023
(In millions)	(In millions)	Asset		Liability		Net Asset (Liability)		Balance Sheet Location	(In millions)	Asset		Liability		Net Asset (Liability)		Balance Sheet Location
Not Designated as Hedges	Not Designated as Hedges								Not Designated as Hedges
Commodity	Commodity	$	—	$	—	$	—	Other current assets	Commodity	$	3	$	—	$	3	Other current assets
Commodity		1		12		(11)		Other current liabilities

Total Not Designated as Hedges	Total Not Designated as Hedges	$	1	$	12	$	(11)		Total Not Designated as Hedges	$	3	$	—	$	3

Cash Flow Hedges	Cash Flow Hedges								Cash Flow Hedges
Interest Rate	Interest Rate	$	8	$	—	$	8	Other current assets	Interest Rate	$	10	$	—	$	10	Other current assets
Interest Rate	Interest Rate	18		—		18		Other noncurrent assets	Interest Rate	15		—		15		Other noncurrent assets

Total Designated Hedges	Total Designated Hedges	$	26	$	—	$	26		Total Designated Hedges	$	25	$	—	$	25
Total	Total	$	27	$	12	$	15		Total	$	28	$	—	$	28

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~


		December 31, 2021								December 31, 2022
(In millions)	(In millions)	Asset		Liability		Net Asset (Liability)		Balance Sheet Location	(In millions)	Asset		Liability		Net Asset (Liability)		Balance Sheet Location
Not Designated as Hedges	Not Designated as Hedges								Not Designated as Hedges
Commodity									Commodity	$	10	$	—	$	10	Other current assets

Commodity		1		8		(7)		Other current liabilities
Interest Rate		27		—		27		Other noncurrent assets

Total Not Designated as Hedges	Total Not Designated as Hedges	$	28	$	8	$	20		Total Not Designated as Hedges	$	10	$	—	$	10

Cash Flow Hedges	Cash Flow Hedges								Cash Flow Hedges
Interest Rate	Interest Rate	$	—	$	3	$	(3)	Other current liabilities	Interest Rate	$	9	$	—	$	9	Other current assets
Interest Rate	Interest Rate	—		2		(2)		Deferred credits and other liabilities	Interest Rate	15		—		15		Other noncurrent assets
Total Designated Hedges	Total Designated Hedges	$	—	$	5	$	(5)		Total Designated Hedges	$	24	$	—	$	24
Total	Total	$	28	$	13	$	15		Total	$	34	$	—	$	34

Derivatives Not Designated as Hedges

Commodity Derivatives

We have entered into ~~multiple~~ crude oil and natural gas derivatives indexed to ~~the~~their respective indices as noted in the table below, related to a portion of our forecasted U.S. sales through ~~the first quarter of 2023.~~2023 and 2024. These derivatives ~~consist of~~are three-way ~~collars, two-way collars and NYMEX roll basis swaps.~~collars. Three-way collars consist of a sold call (ceiling), a purchased put (floor) and a sold put. The ceiling price is the maximum we will receive for the contract volumes; the floor is the minimum price we will receive, unless the market price falls below the sold put strike price. In this case, we receive the NYMEX WTI price or the Henry Hub price plus the difference between the floor and the sold put price. These crude oil and natural gas derivatives were not designated as hedges.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

The following table sets forth outstanding derivative contracts as of September 30, ~~2022,~~2023, and the weighted average prices for those contracts:


		2022		2023			2023	2024
		Fourth Quarter		First Quarter					Fourth Quarter		First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Crude Oil	Crude Oil					Crude Oil
NYMEX WTI Three-Way Collars	NYMEX WTI Three-Way Collars					NYMEX WTI Three-Way Collars
Volume (Bbls/day)	Volume (Bbls/day)	30,000		—		Volume (Bbls/day)			10,000		20,000		20,000		—		—
Weighted average price per Bbl:	Weighted average price per Bbl:					Weighted average price per Bbl:
Ceiling	Ceiling	$	97.52	$	—	Ceiling			$	97.59	$	100.06	$	100.06	$	—	$	—
Floor	Floor	$	56.67	$	—	Floor			$	60.00	$	67.50	$	67.50	$	—	$	—
Sold put	Sold put	$	46.67	$	—	Sold put			$	45.00	$	52.50	$	52.50	$	—	$	—

NYMEX Roll Basis Swaps
Volume (Bbls/day)		60,000		—
Weighted average price per Bbl		$	0.67	$	—

Natural Gas	Natural Gas					Natural Gas
Henry Hub (“HH”) Two-Way Collars
Volume (MMBtu/day)		50,000		50,000
Weighted average price per MMBtu:
Ceiling		$	19.28	$	19.28
Floor		$	5.00	$	5.00

Henry Hub Three-Way Collars	Henry Hub Three-Way Collars					Henry Hub Three-Way Collars
Volume (MMBtu/day)	Volume (MMBtu/day)	100,000		—		Volume (MMBtu/day)			50,000		—		—		$	—	—
Weighted average price per MMBtu:	Weighted average price per MMBtu:					Weighted average price per MMBtu:
Ceiling	Ceiling	$	7.13	$	—	Ceiling			$	11.14	$	—	$	—	$	—	$	—
Floor	Floor	$	3.88	$	—	Floor			$	4.00	$	—	$	—	$	—	$	—
Sold Put	Sold Put	$	2.88	$	—	Sold Put			$	2.50	$	—	$	—	$	—	$	—

The following table sets forth outstanding derivative contracts as of October 31, 2023, with their weighted average prices, and is inclusive of activities that occurred subsequent to September 30, 2023:


	2023	2024
			Fourth Quarter		First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Crude Oil
NYMEX WTI Three-Way Collars
Volume (Bbls/day)			10,000		40,000		40,000		20,000		20,000
Weighted average price per Bbl:
Ceiling			$	97.59	$	101.01	$	101.01	$	101.95	$	101.95
Floor			$	60.00	$	66.25	$	66.25	$	65.00	$	65.00
Sold put			$	45.00	$	51.25	$	51.25	$	50.00	$	50.00





















Natural Gas






Henry Hub Three-Way Collars
Volume (MMBtu/day)			50,000		—		—		$	—	—
Weighted average price per MMBtu:
Ceiling			$	11.14	$	—	$	—	$	—	$	—
Floor			$	4.00	$	—	$	—	$	—	$	—
Sold Put			$	2.50	$	—	$	—	$	—	$	—

1718

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

The unrealized and realized gain (loss) impact of our commodity derivative instruments appears in the table below and is reflected in net gain (loss) on commodity derivatives in the consolidated statements of income.


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		2022		2021		(In millions)	2023		2022		2023		2022
Unrealized gain (loss) on derivative instruments, net	Unrealized gain (loss) on derivative instruments, net	$	67	$	27	$	(4)	$	(130)	Unrealized gain (loss) on derivative instruments, net	$	(6)	$	67	$	(8)	$	(4)
Realized gain (loss) on derivative instruments, net(a)	Realized gain (loss) on derivative instruments, net(a)	$	(26)	$	(106)	$	(125)	$	(268)	Realized gain (loss) on derivative instruments, net(a)	$	7	$	(26)	$	27	$	(125)

(a)During the third quarter and first nine months of 2023, net cash received for settled derivative positions was $6 million and $23 million, respectively. During the third quarter and first nine months of 2022, net cash paid for settled derivative positions was $56 million and $145 million, respectively. ~~During the third quarter and first nine months of 2021, net cash paid for settled derivative positions was $108 million and $203 million, respectively.~~

Interest Rate Swaps

During 2020, we entered into forward starting interest rate swaps with a notional amount of $500 million to hedge the variations in cash flows related to fluctuations in the London Interbank Offered Rate (“LIBOR”) benchmark interest rate related to forecasted interest payments of a future debt issuance in 2022. Each respective derivative contract can be tied to an anticipated underlying dollar notional amount. During the third quarter of 2020, we de-designated these forward starting interest rate swaps previously designated as cash flow hedges. In the first quarter of 2021, the net deferred loss of $2 million in accumulated other comprehensive income related to these de-designated forward starting interest rate swaps was reclassified from accumulated other comprehensive income into earnings as an adjustment to net interest, as we fully redeemed the remainder of our outstanding 2022 notes in April 2021. We recorded a $5 million~~mark-to-market gain and a $24 millionmark-to-market gain within net interest to reflect the change in value of these interest rate swaps during the three and nine months ended September 30, 2021, respectively.~~

During 2020, we entered into forward starting interest rate swaps with a notional amount of $350 million to hedge variations in cash flows arising from fluctuations in the LIBOR benchmark interest rate related to forecasted interest payments of a future debt issuance in 2025. The expected proceeds of the future debt issuance were intended to refinance ~~the~~our $900 million 3.85% Senior Notes due 2025 (“2025 Notes”). In September 2021, we fully redeemed these 2025 Notes. We recorded a $3 million mark-to-market gain and a $34 million mark-to-market gain within net interest to reflect the change in value of these interest rate swaps during the three and nine months ended September 30, 2021. In March 2022, we closed these positions and settled the interest rate swaps for proceeds of $44 million. During the nine months ended September 30, 2022, we recorded a cumulative $17 million gain within net interest ~~for~~and other within our consolidated statements of income related to these swaps.

~~During the second quarter of 2021, we de-designated $25 million of the $320 million Houston office cash flow hedges (discussed further in the~~ ~~Derivatives Designated as Cash Flow Hedges~~ section below), as the construction cost budget estimate was reduced. These interest rate swap contracts began to settle in January 2022. On June 10, 2022, we closed the $25 million de-designated hedges, which resulted in cash proceeds of approximately $2 million. As of September 30, 2022, the remaining open interest rate swaps for the Houston office (with a notional amount of $295 million) are still classified as cash flow hedges.

~~The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements. These positions were fully liquidated as of September 30, 2022.~~
September 30, 2022 December 31, 2021
Maturity Date
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
June 1, 2025 $ — — % $ 350 0.95 %
September 9, 2026 $ — — % $ 25 1.45 %

Derivatives Designated as Cash Flow Hedges

During 2019, we entered into forward starting interest rate swaps with a ~~total notional amount~~maturity date of ~~$320 million~~September 9, 2026 to hedge variations in cash flows related to the ~~1-month LIBOR~~interest rate component of future lease payments of our Houston office. ~~During~~As of September 30, 2023 and December 31, 2022, the ~~second quarter of 2021, we de-designated $25 million of these hedges as the construction cost budget estimate associated with the project was reduced (see discussion in preceding section). The~~ notional amount of open interest rate swaps for the Houston office iswas $295 million.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

The weighted average secured overnight financing rate (“SOFR”) for the swaps was 1.43% as of both September 30, 2023 and December 31, 2022.

The Houston office lease commenced in September 2021, however, our first cash lease payment for February 2022 rent was paid in ~~March.~~March 2022. The first settlement date for the interest rate swaps was in January 2022. ~~The last swap will mature in September 2026.~~ During the ~~third quarter and first~~ nine months of~~2022,~~ended September 30, 2023, net cash ~~received/paid~~received for the settled interest rate swap positions was ~~immaterial.~~$8 million. As of September 30, ~~2022,~~2023, we expect to reclassify $8a $11 million gain from accumulated other comprehensive income into ~~the~~our consolidated statements of income ~~statement~~ over the next twelve months. See Note 121 1 for further details regarding ~~the lease of the~~ Houston ~~office.~~office lease.

~~The following table presents, by maturity date, information about our interest rate swap agreements, including the fixed weighted average LIBOR.~~

September 30, 2022 December 31, 2021
Maturity Date
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
Aggregate Notional Amount
(in millions)
Weighted Average, LIBOR
September 9, 2026 $ 295 1.52 % $ 295 1.52 %

~~14.~~13. Fair Value Measurements

Fair Values – Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, ~~2022~~2023 and December 31, ~~2021~~2022 by hierarchy level.


		September 30, 2022									September 30, 2023
(In millions)	(In millions)	Level 1		Level 2		Level 3		Total		(In millions)	Level 1		Level 2		Level 3		Total
Derivative instruments, assets	Derivative instruments, assets									Derivative instruments, assets

Commodity(a)										Commodity(a)	$	—	$	3	$	—	$	3

Interest rate - designated as cash flow hedges	Interest rate - designated as cash flow hedges	$	—	$	26	$	—	$	26	Interest rate - designated as cash flow hedges	—		25		—		25
Derivative instruments, assets	Derivative instruments, assets	$	—	$	26	$	—	$	26	Derivative instruments, assets	$	—	$	28	$	—	$	28
Derivative instruments, liabilities
Commodity(a)		$	(2)	$	(9)	$	—	$	(11)

Derivative instruments, liabilities		$	(2)	$	(9)	$	—	$	(11)
Total		$	(2)	$	17	$	—	$	15

December 31, 2021
(In millions) Level 1 Level 2 Level 3 Total
Derivative instruments, assets
Interest rate - not designated as cash flow hedges $ — $ 27 $ — $ 27
Derivative instruments, assets $ — $ 27 $ — $ 27
Derivative instruments, liabilities
Commodity(a)
$ (2) $ (5) $ — $ (7)
Interest rate - designated as cash flow hedges — (5) — (5)
Derivative instruments, liabilities $ (2) $ (10) $ — $ (12)
Total $ (2) $ 17 $ — $ 15

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)


	December 31, 2022
(In millions)	Level 1		Level 2		Level 3		Total
Derivative instruments, assets
Commodity(a)	$	—	$	10	$	—	$	10
Interest rate - designated as cash flow hedges	—		24		—		24
Derivative instruments, assets	$	—	$	34	$	—	$	34

(a)Commodity derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 1312.

~~Commodity~~As of September 30, 2023, our commodity derivatives include three-way ~~collars, two-way collars and NYMEX roll basis swaps.~~collars. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. For commodity swaps, inputs to the models include only commodity prices and interest rates and are categorized as Level 1 because all assumptions and inputs are observable in active markets throughout the term of the instruments. For three-way ~~collars 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.

The forward starting interest rate swaps are measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 1312 for ~~detail~~details on the forward starting interest rate swaps.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~Fair Values – Nonrecurring~~

~~See~~ ~~Note 10for detail on our fair values related to impairments.~~

Fair Values – Financial Instruments

Our current assets and liabilities include financial instruments, the most significant of which are receivables, 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 September 30, ~~2022~~2023 and December 31, ~~2021.~~2022.


		September 30, 2022				December 31, 2021					September 30, 2023				December 31, 2022
(In millions)	(In millions)	Fair Value		Carrying Amount		Fair Value		Carrying Amount		(In millions)	Fair Value		Carrying Amount		Fair Value		Carrying Amount
Financial assets	Financial assets									Financial assets
Current assets		$	—	$	—	$	11	$	10

Other noncurrent assets	Other noncurrent assets	10		28		12		27		Other noncurrent assets	$	9	$	27	$	10	$	28
Total financial assets	Total financial assets	$	10	$	28	$	23	$	37	Total financial assets	$	9	$	27	$	10	$	28
Financial liabilities	Financial liabilities									Financial liabilities
Current liabilities		$	107	$	171	$	99	$	136
Other current liabilities										Other current liabilities	$	132	$	198	$	140	$	204
Long-term debt, including current portion(a)	Long-term debt, including current portion(a)	3,793		3,997		4,705		4,033		Long-term debt, including current portion(a)	5,126		5,297		5,806		5,948
Deferred credits and other liabilities	Deferred credits and other liabilities	16		15		46		46		Deferred credits and other liabilities	45		45		73		73
Total financial liabilities	Total financial liabilities	$	3,916	$	4,183	$	4,850	$	4,215	Total financial liabilities	$	5,303	$	5,540	$	6,019	$	6,225

(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.

~~All of our long-term~~Our fixed rate debt instruments are publicly traded. AThe fair value of our fixed rate debt is measured using a market approach, based upon quotes from major financial institutions, which are Level 2 ~~inputs,~~inputs. Our floating rate debt is ~~used to measure the~~non-public and consists of borrowings under our Term Loan Facility and Revolving Credit Facility. The fair value of our ~~debt.~~floating rate debt approximates the carrying value and is estimated based on observable market-based inputs, which results in a Level 2 classification.

~~15.~~

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

14. Debt

Term Loan Facility

In November 2022, we entered into a term credit agreement, which provides for a two-year $1.5 billion term loan facility (“Term Loan Facility”) and we borrowed the full amount thereunder in December 2022. Borrowings under the Term Loan Facility can be prepaid without penalty. As of September 30, 2023, we had $1.5 billion in borrowings under our Term Loan Facility. The third quarter weighted average interest rate on borrowings under the Term Loan Facility was 7.10%.

The Term Loan Facility includes a covenant requiring our total debt to total capitalization ratio not to exceed 65% as of the last day of each fiscal quarter. In the event of a default, the lenders holding more than half of the commitments may terminate all of the commitments under the Term Loan Facility and require the immediate repayment of all outstanding borrowings under the Term Loan Facility. As of September 30, 2023, we were in compliance with this covenant with a ratio of 26%.

Subsequent to the quarter, we repaid $250 million of outstanding borrowings on October 31, 2023. We have $1.3 billion in borrowings remaining under our Term Loan Facility.

Revolving Credit Facility

~~As of~~In September ~~30, 2022,~~2023, we ~~had no borrowings against~~increased our $2.5 billion unsecured ~~revolving credit facility (“~~Revolving Credit ~~Facility”).~~

OnFacility by $61 million to a total of $2.6 billion. Fees on the unused commitment of each lender, as well as the borrowing options under the Revolving Credit Facility, remain unaffected by the increase. 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 maturity remains July 28, ~~2022,~~2027.

During the third quarter of 2023, we ~~executed the seventh amendment~~utilized commercial paper borrowings to fully repay our outstanding borrowings against our $2.6 billion unsecured Revolving Credit Facility. The ~~primary changes to~~third quarter weighted average interest rate on borrowings under the Revolving Credit Facility effected by this amendment were to (i) extend the maturity date of the Credit Facility by three years to July 28, 2027, (ii) decrease the size of the Credit Facility from $3.1 billion to $2.5 billion, (iii) replace the LIBOR interest rate benchmark with the secured overnight financing rate (“SOFR”) and (iv) implement certain revisions to the Pricing Schedule.was 6.82%.

The Revolving Credit Facility includes a covenant requiring our total debt to total capitalization ratio not to exceed 65% as of the last day of each fiscal quarter. In the event of a default, the lenders holding more than half of the commitments may terminate the commitments under the Revolving Credit Facility and require the immediate repayment of all outstanding borrowings and the cash collateralization of all outstanding letters of credit under the Revolving Credit Facility. As of September 30, ~~2022,~~2023, we were in compliance with this covenant with a ratio of ~~20%~~26%.

Commercial Paper Program

During the second quarter of 2023, we obtained ratings for our commercial paper from Moody’s, Standard & Poor’s and Fitch. Pursuant to our 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.

During the third quarter of 2023, we utilized our recently established commercial paper program to fund various short-term working capital requirements. As of September 30, 2023, we had $450 million of outstanding commercial paper maturing at various dates. The third quarter weighted average interest rate for commercial paper borrowings was 6.19%.

Debt Redemption

~~In May 2022,~~On July 17, 2023, we ~~redeemed~~repaid the ~~$32~~$131 million ~~9.375%~~8.125% Senior Notes ~~on the~~in connection with their maturity date.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~In September 2021,~~On March 1, 2023, we ~~redeemed our outstanding $900~~repaid the $70 million ~~3.85%~~8.5% Senior Notes ~~due 2025 (“2025 Notes”). We incurred $102 million~~ in ~~costs related to the make-whole provision premium and the write off of unamortized discount and issuance costs.~~

In April 2021, we redeemed our outstanding $500 million 2.8% Senior Notes due 2022 (“2022 Notes”). We incurred $19 million in costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs.connection with their maturity date.

Long-term debt

At September 30, ~~2022,~~2023, we had ~~$4.0~~$5.3 billion of total long-term debt ~~outstanding, which includes $402 million of long-term debt due within one year. Included in long-term~~outstanding. Long-term debt due within one year isconsists of $200 million ~~in 2.0%~~2.1% Bonds and $200 million 2.125% Bonds which feature a mandatory put on ~~April~~July 1, ~~2023.~~2024. Refer to our ~~2021~~2022 Annual Report on Form 10-K for a listing of our long-term debt maturities.

Debt Remarketing

~~16.~~On April 3, 2023, we closed a $200 million remarketing to investors of sub-series 2017A-1 bonds that are part of the $1 billion St. John the Baptist Parish, State of Louisiana revenue refunding bonds Series 2017. The bonds are subject to an interest rate of 4.05% and a mandatory purchase date of July 1, 2026. The repayments and new borrowings associated with the remarketed bonds are presented separately within Debt repayments and Borrowings, respectively, within the Consolidated Statements of Cash Flows.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

15. Stockholders’ Equity

Our Board of Directors has authorized a share repurchase program. During the first nine months of ~~2022,~~2023, we repurchased approximately ~~$2.5 billion of~~45 million shares of our common stock pursuant to the share repurchase ~~program. The total~~program at a cost of $1.1 billion. Our remaining share repurchase authorization was approximately ~~$926 million~~$1.4 billion at September 30, ~~2022.~~2023. Purchases under the program are made at our discretion and may be in either open market transactions, including block purchases, or in privately negotiated transactions using cash on hand, cash generated from operations or proceeds from potential asset sales. This program may be changed based upon our financial condition or changes in market conditions and is subject to termination prior to completion.

Additionally, during the first nine months of ~~2022~~2023 we repurchased ~~$21~~$31 million of shares related to our tax withholding obligation associated with the vesting of ~~employee restricted stock awards and restricted stock units;~~stock-based compensation awards; these repurchases do not impact our share repurchase program authorization.

Subsequent to the quarter, we repurchased approximately ~~$230~~$145 million of shares of our common stock through November ~~2, 2022.~~1, 2023. Effective November ~~2, 2022,~~1, 2023, our Board of Directors increased our remaining share repurchase program authorization to $2.5 billion.

~~17.~~16. Incentive Based Compensation

Stock options, restricted stock and restricted stock units

The following table presents a summary of activity for the first nine months of ~~2022:~~2023:


		Stock Options			Restricted Stock & Units				Stock Options			Restricted Stock & Units
		Number of Shares	Weighted Average Exercise Price		Number of Shares & Units	Weighted Average Grant Date Fair Value			Number of Shares	Weighted Average Exercise Price		Number of Shares & Units	Weighted Average Grant Date Fair Value
Outstanding at December 31, 2021		4,274,304	$	22.13	5,888,242	$	10.98
Outstanding at December 31, 2022								Outstanding at December 31, 2022	1,678,524	$	28.86	4,651,196	$	14.89
Granted	Granted	—	$	—	1,719,757	$	22.83	Granted	—	$	—	1,845,409	$	25.77
Exercised/Vested	Exercised/Vested	(1,842,093)	$	14.41	(2,796,967)	$	12.05	Exercised/Vested	(184,028)	$	10.47	(2,729,366)	$	12.49
Canceled	Canceled	(414,952)	$	33.55	(187,859)	$	14.14	Canceled	(374,431)	$	34.41	(159,450)	$	21.05
Outstanding at September 30, 2022		2,017,259	$	26.82	4,623,173	$	14.62
Outstanding at September 30, 2023								Outstanding at September 30, 2023	1,120,065	$	30.03	3,607,789	$	21.99

Stock-based performance unit awards

During the first nine months of ~~2022,~~2023, we granted ~~167,043~~222,464 stock-based performance units to eligible officers, which are settled in shares. The grant date fair value per unit was ~~$34.07.~~$32.97. During the first nine months of ~~2022,~~2023, we stock settled the units related to the 2020 grant. At September 30, 2023, there were 686,266 outstanding stock-based performance units to be settled in shares to officers.

During the first nine months of 2023, we also granted ~~167,043~~222,464 stock-based performance units to eligible officers, which are settled in cash. At the grant date for these performance units, each unit represents the value of one share of our common stock. The fair value of each cash-settled performance unit was ~~$23.37~~$27.05 as of September 30, ~~2022.~~2023. During the first nine months of 2023, we also cash settled the units related to the 2021 grant. At September 30, 2023, there were 389,507 units outstanding of the stock-based performance unit awards to be settled in cash to officers.

2122

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

~~18.~~

17. Defined Benefit Postretirement Plans

The following table summarizes the components of net periodic benefit costs (credits):


		Three Months Ended September 30,									Three Months Ended September 30,
		Pension Benefits				Other Benefits					Pension Benefits				Other Benefits
(In millions)	(In millions)	2022		2021		2022		2021		(In millions)	2023		2022		2023		2022
Service cost	Service cost	$	4	$	4	$	—	$	—	Service cost	$	4	$	4	$	—	$	—
Interest cost	Interest cost	1		2		1		—		Interest cost	2		1		1		1
Expected return on plan assets	Expected return on plan assets	(2)		(2)		—		—		Expected return on plan assets	(3)		(2)		—		—
Amortization:	Amortization:									Amortization:
– prior service credit	– prior service credit	(1)		(1)		(4)		(4)		– prior service credit	(1)		(1)		(4)		(4)
– actuarial loss	– actuarial loss	—		1		—		1		– actuarial loss	—		—		—		—
Net settlement loss(a)	Net settlement loss(a)	—		3		—		—		Net settlement loss(a)	—		—		—		—

Net periodic benefit costs (credits)(b)	Net periodic benefit costs (credits)(b)	$	2	$	7	$	(3)	$	(3)	Net periodic benefit costs (credits)(b)	$	2	$	2	$	(3)	$	(3)


		Nine Months Ended September 30,									Nine Months Ended September 30,
		Pension Benefits				Other Benefits					Pension Benefits				Other Benefits
(In millions)	(In millions)	2022		2021		2022		2021		(In millions)	2023		2022		2023		2022
Service cost	Service cost	$	11	$	12	$	—	$	—	Service cost	$	11	$	11	$	—	$	—
Interest cost	Interest cost	5		6		2		1		Interest cost	8		5		2		2
Expected return on plan assets	Expected return on plan assets	(7)		(6)		—		—		Expected return on plan assets	(7)		(7)		—		—
Amortization:	Amortization:									Amortization:
– prior service credit	– prior service credit	(4)		(4)		(12)		(12)		– prior service credit	(4)		(4)		(12)		(12)
– actuarial loss	– actuarial loss	1		4		1		2		– actuarial loss	—		1		1		1
Net settlement loss(a)	Net settlement loss(a)	—		8		—		—		Net settlement loss(a)	1		—		—		—

Net periodic benefit costs (credits)(b)	Net periodic benefit costs (credits)(b)	$	6	$	20	$	(9)	$	(9)	Net periodic benefit costs (credits)(b)	$	9	$	6	$	(9)	$	(9)

(a)Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan’s total service and interest cost for that year.

(b)Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets which recognizes changes in fair value over three years.

During the first nine months of ~~2022,~~2023, we made contributions of ~~$17~~$19 million to our funded pension ~~plan.~~plan and we expect to make additional contributions of $4 million this year. We also made ~~a payment~~payments of $7$3 million ~~related~~and $5 million to our unfunded pension plan and other postretirement benefit ~~plans. We expect to contribute an additional $4 million in contributions to our funded pension plan this year.~~

plans, respectively.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~19.~~18. Reclassifications Out of Accumulated Other Comprehensive Income (Loss)

The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss):


		Three Months Ended September 30,				Nine Months Ended September 30,						Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		2022		2021		Income Statement Line	(In millions)	2023		2022		2023		2022		Income Statement Line
Postretirement and postemployment plans	Postretirement and postemployment plans										Postretirement and postemployment plans
Amortization of prior service credit	Amortization of prior service credit	$	5	$	5	$	16	$	16	Other net periodic benefit costs	Amortization of prior service credit	$	5	$	5	$	16	$	16	Other net periodic benefit credits
Amortization of actuarial loss	Amortization of actuarial loss	—		(2)		(2)		(6)		Other net periodic benefit costs	Amortization of actuarial loss	—		—		(1)		(2)		Other net periodic benefit credits
Net settlement loss	Net settlement loss	—		(3)		—		(8)		Other net periodic benefit costs	Net settlement loss	—		—		(1)		—		Other net periodic benefit credits

Interest rate swaps
Reclassification of de-designated forward interest rate swaps		—		—		—		(28)		Net interest and other

		(1)		—		(3)		—		Provision for income taxes
Total reclassifications of (income) expense, net of tax (a)		$	4	$	—	$	11	$	(26)	Net income (loss)
Income Tax											Income Tax	(1)		(1)		(3)		(3)		Provision (benefit) for income taxes
Total reclassifications of expense, net of tax											Total reclassifications of expense, net of tax	$	4	$	4	$	11	$	11	Net income

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

19. Supplemental Cash Flow Information


	Nine Months Ended September 30,
(In millions)	2023		2022
Included in operating activities:
Interest paid(a)	$	251	$	153
Income taxes paid, net of refunds	$	103	$	128
Noncash investing activities:
Increase in asset retirement costs	$	16	$	9

(a)~~During 2021 we had a full valuation allowance on net federal deferred tax assets in~~The increase during the ~~U.S. and as such, there is no tax impact to our postretirement and postemployment plans for the three and~~ nine months ended September 30, ~~2021.~~

~~20. Supplemental Cash Flow Information~~

Nine Months Ended September 30,
(In millions) 2022 2021
Included in operating activities:
Interest paid $ 153 $ 185
Income taxes paid, net of refunds (a)
$ 128 $ 8
Noncash investing activities:
Increase in asset retirement costs $ 9 $ 49

~~(a)The nine months ended September 30, 2021 includes $1 million~~2023 compared to the same period in 2022 was primarily related to ~~tax refunds.~~interest paid on borrowings under the Term Loan Facility and Revolving Credit Facility.

Other noncash investing activities include accrued capital expenditures for the nine months ended September 30, 2023 and 2022 of $125 million and ~~2021 of~~ $99 million, ~~and $104 million,~~ respectively.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~21.~~20. Equity Method Investments

During the periods ended September 30, ~~2022~~2023 and December 31, ~~2021~~2022 our equity method investees were considered related parties. Our investment in our equity method investees are summarized in the following table:
(In millions) Ownership as of September 30, 2022 September 30, 2022 December 31, 2021
EGHoldings (a)
56% $ 293 $ 148
Alba Plant LLC (b)
52% 142 154
AMPCO (c)
45% 133 148
Total $ 568 $ 450


(In millions)	Ownership as of September 30, 2023	September 30, 2023		December 31, 2022
EGHoldings (a)	56%	$	108	$	287
Alba Plant LLC (b)	52%	160		155
AMPCO (c)	45%	153		135
Total		$	421	$	577

(a)EGHoldings is engaged in LNG production activity.

(b)Alba Plant LLC processes LPG.

(c)AMPCO is engaged in methanol production activity.

Summarized, 100% combined financial information for equity method investees is as follows:

Three Months Ended September 30, Nine Months Ended September 30,
(In millions) 2022 2021 2022 2021
Income data:
Revenues and other income $ 499 $ 325 $ 1,332 $ 806
Income from operations 358 188 893 395
Net income $ 335 $ 155 $ 811 $ 312


	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2023		2022		2023		2022
Income data:
Revenues and other income	$	200	$	499	$	689	$	1,332
Income from operations	77		358		279		893
Net income	$	63	$	335	$	227	$	811

Revenues from related parties were $6 million and $17 million for the three and nine months ended September 30, 2023 and $7 million and $22 million for the three and nine months ended September 30, 2022, respectively, ~~$8 million and $24 million for the three and nine months ended September 30, 2021, respectively,~~ with the majority related to EGHoldings in ~~all~~both periods.

Cash received from equity investees is classified as dividends or return of capital on the Consolidated Statements of Cash Flows. Dividends from equity method investees are reflected in the Operating activities section in Equity Method Investments, net while return of capital is reflected in the Investing activities section. Dividends and return of capital received by us totaled $47 million and $296 million during the three and nine months ended September 30, 2023 and $150 million and $350 million ~~for~~during the three and nine months ended September 30, 2022, ~~respectively, and $56 million and $137 million for the three and nine months ended September 30, 2021,~~ respectively.

Current receivables from related parties at September 30, ~~2022 and December 31, 2021~~2023 were ~~$43 million and $23 million, respectively, with the majority related to EGHoldings in both periods. Payables to related parties at September 30, 2022 were $6~~$24 million with the majority related to EGHoldings and ~~$20~~$36 million at December 31, ~~2021,~~2022 which primarily related to Alba Plant LLC and EGHoldings. Payables to related parties at September 30, 2023 and December 31, 2022 were $17 million and $20 million, respectively, with the majority related to Alba Plant ~~LLC.~~LLC in both periods.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

~~22.~~

21. Commitments and Contingencies

Various groups, including the State of North Dakota and ~~three~~the Mandan, Hidatsa and Arikara Nation or MHA Nation, also known as the Three Affiliated Tribes of the Fort Berthold Indian ~~tribes~~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 September 30, ~~2022,~~2023, we have a ~~$153~~$168 million current liability in suspended royalty and working interest revenue, including interest, of which ~~$138~~$144 million was included within accounts payable and ~~$15~~$24 million related to accrued interest ~~and~~ was included within other current liabilities on our consolidated balance sheet. Additionally, we have a long-term receivable of $26 million for capital and expenses. To address a potential dispute with the Three Affiliated Tribes over the validity of certain of our leases, Marathon Oil has entered into an agreement pursuant to which we will pay an amount representing $50 million of the suspended royalties (inclusive of interest thereon) to the Three Affiliated Tribes. The agreement allows Marathon to recover all funds paid to the Three Affiliated Tribes (including by offsetting against production from other minerals leased to Marathon by the Three Affiliated Tribes) if a court ultimately determines that the Disputed Land is not held in trust for the Three Affiliated Tribes, but instead is owned by the State of North Dakota. The United States Department of the Interior (“DOI”) has addressed the United States’ position with respect to this dispute several times ~~over the past five~~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 (“2022 M-Opinion”) concluding ~~the DOI’s position~~ that the Disputed Land is held in trust for the Three Affiliated Tribes. While the 2022 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. Depending on the ultimate outcome of this title dispute, the Three Affiliated Tribes could challenge the validity of certain of our leases relating to a portion of the disputed land, and if such challenge were successful it could result in operational delays and additional costs to us. Given the uncertainty in matters such as these, we are unable to predict the ultimate outcome of this matter at this time; however, we believe the resolution of this matter will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.

We are a defendant in a number of legal and administrative proceedings arising in the ordinary course of business including, but not limited to, royalty claims, contract claims, tax disputes and environmental claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. In addition, we may also be subject to retained liabilities with respect to certain divested assets by operation of law. For example, we are exposed to the risk that owners and/or operators of assets purchased from us become unable to satisfy plugging or abandonment obligations that attach to those assets. In that event, due to operation of law, we may be required to assume plugging or abandonment obligations for those assets. Although we have established reserves for such liabilities, we could be required to accrue additional amounts in the future and these amounts could be material.

Marathon Oil ~~has been named in various lawsuits alleging royalty underpayments in our domestic operations. We intend to vigorously defend ourselves against such claims. For instance, Marathon Oil~~ was named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and after plaintiffs lost their attempt to certify a class action, a settlement ~~in principle~~ was reached, ~~subject to~~and in the first quarter of 2023 such settlement was approved by the court ~~approval.~~ and paid.

We have accrued for potential liabilities associated with these lawsuits based on currently available information; however, actual losses may exceed our accruals or we could be required to accrue additional amounts in the future.

~~In January 2020, we~~ received a Notice of ~~Violation~~Violations (“NOV”)’s from the EPA related to allegations of violations of the Clean Air Act ~~relating~~with respect to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. We ~~are~~continue to actively ~~negotiating~~negotiate a draft consent decree with the EPA and Department of ~~Justice containing certain proposed injunctive terms relating to this enforcement action.~~Justice. The resolution of the enforcement action will likely include monetary sanctions and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. We maintain an accrual for estimated ~~future costs related to this matter regarding actions required to retrofit or replace existing equipment, which we expect to incur over multiple years. Our accrual does not include possible~~potential monetary ~~sanctions or costs associated with mitigation projects as we are unable to estimate those amounts.~~sanctions. Through the date of this filing, there exists substantial uncertainty as to the ultimate result of this matter and it is reasonably possible the result could be materially different from our expectations and our accrual.

~~In July 2022, the~~

The Company received ~~an NOV~~NOV’s from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 and 2022 over certain of the Company’s oil and gas facilities in New Mexico. The ~~notice involves~~notices involve alleged emission and permitting violations. ~~The Company has~~We initiated discussions with the EPA to resolve these matters. ~~As we are still investigating these allegations,~~At this time, we are unable to estimate the potential loss associated with ~~this matter,~~these matters, however, it is reasonably possible that ~~the~~ resolution of these matters may result in a fine or penalty in ~~excess~~excess of $300,000.

Table of Contents

MARATHON OIL CORPORATION

Notes to Consolidated Financial Statements (Unaudited)

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 September 30, ~~2022,~~2023, accrued liabilities for remediation relating to environmental laws and regulations were not material. It is not presently possible to estimate the ultimate amount of all remediation cost that might be incurred or the penalties that may be imposed.

In the second quarter of 2019, Marathon E.G. Production Limited (“MEGPL”), a consolidated and wholly owned subsidiary, signed a series of agreements to process third-party Alen Unit gas through existing infrastructure located in Punta Europa, E.G. Our equity method investee, Alba Plant LLC, is also a party to some of the agreements. These agreements require (subject to certain limitations) MEGPL to indemnify the owners of the Alen Unit against injury to Alba Plant LLC’s personnel and damage to or loss of Alba Plant LLC’s automobiles, as well as third party claims caused by Alba Plant LLC and certain environmental liabilities arising from certain hydrocarbons in the custody of Alba Plant LLC. At this time, we cannot reasonably estimate this obligation as we do not have any history of prior indemnification claims or environmental discharge or contamination. Therefore, we have not recorded a liability with respect to these indemnities since the amount of potential future payments under these indemnification clauses is not determinable.

The agreements to process the third-party Alen Unit gas required the execution of third-party guarantees by Marathon Oil Corporation in favor of the Alen Unit’s owners. Two separate guarantees were executed during the second quarter of 2020; one for a maximum of approximately $91 million pertaining to the payment obligations of Equatorial Guinea LNG Operations, S.A. and another for a maximum of $25 million pertaining to the payment obligations of Alba Plant LLC. Payment by us would be required if any of those entities fails to honor its payment obligations pursuant to the relevant agreements with the owners of the Alen Unit. Certain owners of the Alen Unit, or their affiliates, are also direct or indirect shareholders in Equatorial Guinea LNG Operations, S.A. and Alba Plant LLC. Each guarantee expires no later than December 31, 2027. We measured these guarantees at fair value using the net present value of premium payments we expect to receive from our investees. Our liability for these guarantees was approximately $4 million as of September 30, ~~2022.~~2023. Each of Equatorial Guinea LNG Operations, S.A. and Equatorial Guinea LNG Train 1, S.A. provided us with a pledge of its receivables as recourse against any payments we may make under the guaranty of Equatorial Guinea LNG Operations, S.A.’s performance.

~~MARATHON OIL CORPORATION~~

~~Notes to Consolidated Financial Statements (Unaudited)~~

~~23. Subsequent Event~~

~~On November 2, 2022, we executed a definitive purchase agreement to acquire the assets and certain related liabilities~~Table of Ensign Natural Resources in the Eagle Ford resource play in Texas for total cash consideration of $3.0 billion. The assets primarily consist of approximately 130,000 net proved and unproved acres, with an average 97% working interest, approximately 700 existing wells, and estimated current production of approximately 67,000 net boepd (including 22,000 net bopd of oil). We expect to fund the acquisition using a combination of cash on hand, borrowings on the company’s Credit Facility, and new prepayable debt. The transaction is subject to customary terms and conditions, including closing adjustments, and is expected to close by year-end 2022.

Contents

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

Results of Operations

Critical Accounting Estimates

~~Accounting Standards Not Yet Adopted~~

Cash Flows

Liquidity and Capital Resources

Environmental Matters and Other Contingencies

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the preceding consolidated financial statements and notes in Item 1.

Executive Overview

We are an independent exploration and production company, focused on U.S. resource plays: Eagle Ford in Texas, Bakken in North Dakota, STACK and SCOOP in Oklahoma and ~~Northern Delaware~~Permian in New ~~Mexico.~~Mexico and Texas. Our U.S. assets are complemented by our international operations in E.G. Our overall business strategy is to responsibly deliver competitive corporate return levels, free cash flow and cash returns to shareholders, all of which are sustainable and resilient through long-term commodity price cycles. We expect to achieve our business strategy by adherence to a disciplined reinvestment rate capital allocation framework that limits our capital expenditures relative to our expected cash flow from operations. Keeping our workforce safe, maintaining a strong balance sheet, responsibly meeting global energy demand with a focus on continuously improving environmental performance, serving as a trusted partner in our local communities and maintaining best in-class corporate governance standards are foundational to the execution of our strategy.

~~As discussed in~~ ~~Note 23~~ ~~to the consolidated financial statements, on November 2,~~In December 2022, we ~~entered into an agreement~~closed on a transaction to acquire approximately 130,000 net proved and unproved acres, with an average 97% working interest, in the Eagle Ford resource play ~~in Texas. The transaction is subject to customary terms and conditions, including closing adjustments, and is expected to close by year-end 2022.~~from Ensign Natural Resources (“Ensign”) for cash consideration of $3.0 billion.

Compared to the prior year, we experienced a significant increase in revenues, income from operations and operating cash flow, all of which were driven by higher commodity prices. Total company net sales volumes were slightly higher for the quarter and roughly flat for the year-to-date period. Our year-to-date cash generated from operations more than funded our capital program, dividend payments and share repurchases. These results and activities are consistent with our prioritization of free cash flow generation and adherence to our disciplined capital allocation framework. Below are certain key financial and operational highlights for the quarter:

~~Improved financial~~Financial and operational results

•Our net income was ~~$817~~$453 million in the third quarter of ~~2022~~2023 as compared to net income of ~~$184~~$817 million in the same period last year. Included in our financial results for the current quarter:

◦Revenues from contracts with customers ~~increased $570~~decreased $237 million compared to the same quarter last year as a result of lower realized commodity prices, ~~were significantly higher.~~

◦~~Income~~partially offset by increased sales. Lower realized commodity prices also resulted in lower income from equity method investments, ~~totaled $190 million,~~ which ~~is an increase of $104 million due to higher realized prices.~~

◦~~We recorded a net gain of $41 million on commodity derivatives as compared to a net loss of $79 million during the same quarter last year, which increased income by $120 million.~~

◦~~As a result of higher income before taxes, our provision for income taxes increased by $236~~decreased $152 million compared to the same quarter last year. ~~See~~

◦~~Note 6~~Net sales volumes in the U.S. segment increased 25% compared to the ~~consolidated financial statements~~same period last year, primarily driven by increased production from the acreage acquired from Ensign.

◦The increase in net sales volumes resulted in higher depreciation, depletion and amortization expense of $123 million as compared to the same quarter last year.

◦Our provision for ~~discussion~~income taxes decreased $113 million compared to the same quarter last year.

•Upon conclusion of the ~~increase in income taxes.~~third quarter, we announced the signing of a 5-year firm LNG sales agreement for a portion of our equity gas from the Alba Field liquefied at EG LNG. The contract is 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.

2827

Table of Contents

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

•In the first nine months of ~~2022,~~2023, we repurchased ~~approximately $2.5~~$1.1 billion of shares through our share repurchase ~~program, of which $1.1 billion occurred during the current quarter.~~program. In addition, effective November 1, 2023, our Board increased our remaining share repurchase authorization to $2.5 billion.

•As of September 30, ~~2022,~~2023, we have ~~$1.1 billion~~$174 million of cash on hand and ~~$3.6~~$2.3 billion of total liquidity.

•~~Paid $162~~We reduced our long-term debt, including the repayment at maturity of $70 million 8.5% Senior Notes on March 1, 2023 and $131 million 8.125% Senior Notes on July 17, 2023. In addition, subsequent to the quarter, we repaid $250 million of outstanding borrowings on our Term Loan Facility on October 31, 2023.

•During the first nine months of 2023, we paid $186 million of dividends, or $0.30 per share, compared to dividends paid of $0.23 per share during the first nine months of ~~2022, compared~~2022. On October 25, 2023, our Board approved a 10% increase to ~~dividends paid~~our dividend payable to shareholders in the fourth quarter of ~~$0.12~~2023, to $0.11 per ~~share during the first nine months of 2021.~~share.

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

Outlook

Capital Budget

In ~~our 2021 Form 10-K filed in~~ February ~~2022,~~2023, we ~~disclosed~~announced a ~~2022~~2023 capital budget of ~~$1.2~~$1.9 billion ~~based on assumed hydrocarbon prices~~to $2.0 billion that prioritizes free cash flow generation over production growth, consistent with our disciplined capital allocation framework. Our expectation is our full year capital expenditures will be at the higher end of ~~$80/bbl~~our range. Our production targets for ~~WTI and $4/mmbtu for Henry Hub gas,~~2023 include full year oil-equivalent production of 385 - 405 mboed, of which ~~were indicative~~we are also trending towards the higher end of ~~market conditions at that time. Given persistent~~the range. We continue to monitor inflationary pressures given the labor market, commodity prices, supply chain challenges and ~~our efforts to protect execution and operational momentum into 2023, we now expect our capital budget to increase to $1.4 billion.~~

geopolitical instability.

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 September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
Net Sales Volumes	Net Sales Volumes	2022	2021	Increase (Decrease)		2022	2021	Increase (Decrease)		Net Sales Volumes	2023	2022	Increase (Decrease)		2023	2022	Increase (Decrease)
United States (mboed)	United States (mboed)	295	281	5	%	286	280	2	%	United States (mboed)	369	295	25	%	356	286	24	%
International (mboed)	International (mboed)	58	61	(5)	%	59	64	(8)	%	International (mboed)	53	58	(9)	%	51	59	(14)	%
Total (mboed)	Total (mboed)	353	342	3	%	345	344	—	%	Total (mboed)	422	353	20	%	407	345	18	%

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:~~segment. Effective in 2023, the Texas Delaware oil play, which was previously included within Other United States as an exploration property, was integrated into the Permian resource play. The increase in net sales volumes in our U.S. segment compared to the same period in the prior year was primarily a result of our acquisition of the Eagle Ford assets of Ensign in December 2022.


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
Net Sales Volumes	Net Sales Volumes	2022	2021	Increase (Decrease)		2022	2021	Increase (Decrease)		Net Sales Volumes	2023	2022	Increase (Decrease)		2023	2022	Increase (Decrease)
Equivalent Barrels (mboed)	Equivalent Barrels (mboed)									Equivalent Barrels (mboed)
Eagle Ford	Eagle Ford	90	95	(5)	%	85	88	(3)	%	Eagle Ford	158	90	76	%	153	85	80	%
Bakken	Bakken	118	103	15	%	116	107	8	%	Bakken	121	118	3	%	108	116	(7)	%
Oklahoma	Oklahoma	54	55	(2)	%	54	54	—	%	Oklahoma	46	54	(15)	%	50	54	(7)	%
Northern Delaware		24	21	14	%	21	24	(13)	%
Permian										Permian	42	24	75	%	43	21	105	%
Other United States	Other United States	9	7	29	%	10	7	43	%	Other United States	2	9	(78)	%	2	10	(80)	%
Total United States	Total United States	295	281	5	%	286	280	2	%	Total United States	369	295	25	%	356	286	24	%

Table of Contents


	Three Months Ended September 30, 2023
Sales Mix - U.S. Resource Plays	Eagle Ford		Bakken		Oklahoma		Permian		Total
Crude oil and condensate	51	%	64	%	19	%	52	%	51	%
Natural gas liquids	25	%	22	%	29	%	24	%	25	%
Natural gas	24	%	14	%	52	%	24	%	24	%

Three Months Ended September 30, 2022
Sales Mix - U.S. Resource Plays Eagle Ford Bakken Oklahoma Northern Delaware Total
Crude oil and condensate 67 % 64 % 22 % 55 % 56 %
Natural gas liquids 18 % 23 % 35 % 22 % 24 %
Natural gas 15 % 13 % 43 % 23 % 20 %


		Three Months Ended September 30,		Nine Months Ended September 30,			Three Months Ended September 30,		Nine Months Ended September 30,
Drilling Activity - U.S. Resource Plays	Drilling Activity - U.S. Resource Plays	2022	2021	2022	2021	Drilling Activity - U.S. Resource Plays	2023	2022	2023	2022
Gross Operated	Gross Operated					Gross Operated
Eagle Ford:	Eagle Ford:					Eagle Ford:
Wells drilled to total depth	Wells drilled to total depth	22	23	86	76	Wells drilled to total depth	18	22	83	86
Wells brought to sales	Wells brought to sales	48	29	95	99	Wells brought to sales	38	48	123	95
Bakken:	Bakken:					Bakken:
Wells drilled to total depth	Wells drilled to total depth	12	16	36	55	Wells drilled to total depth	19	12	64	36
Wells brought to sales	Wells brought to sales	9	27	49	46	Wells brought to sales	25	9	65	49
Oklahoma:	Oklahoma:					Oklahoma:
Wells drilled to total depth	Wells drilled to total depth	4	—	13	—	Wells drilled to total depth	7	4	11	13
Wells brought to sales	Wells brought to sales	—	4	19	4	Wells brought to sales	4	—	9	19
Northern Delaware:
Permian:						Permian:
Wells drilled to total depth	Wells drilled to total depth	6	—	12	—	Wells drilled to total depth	5	6	19	12
Wells brought to sales	Wells brought to sales	13	3	13	3	Wells brought to sales	9	13	25	13

International

Net sales volumes were lower induring the ~~third quarter~~three and ~~first~~ nine months ~~of of 2022~~ended September 30, 2023 as compared to the ~~third quarter and first nine months of of 2021~~same period in the prior year primarily due to natural decline. The following table provides details regarding net sales volumes for our operations within this segment:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
Net Sales Volumes	Net Sales Volumes	2022	2021	Increase (Decrease)		2022	2021	Increase (Decrease)		Net Sales Volumes	2023	2022	Increase (Decrease)		2023	2022	Increase (Decrease)
Equivalent Barrels (mboed)	Equivalent Barrels (mboed)									Equivalent Barrels (mboed)
Equatorial Guinea	Equatorial Guinea	58	61	(5)	%	59	64	(8)	%	Equatorial Guinea	53	58	(9)	%	51	59	(14)	%

Equity Method Investees	Equity Method Investees									Equity Method Investees
LNG (mtd)	LNG (mtd)	2,536	3,119	(19)	%	2,872	3,186	(10)	%	LNG (mtd)	1,670	2,536	(34)	%	1,831	2,872	(36)	%
Methanol (mtd)	Methanol (mtd)	956	1,218	(22)	%	967	1,137	(15)	%	Methanol (mtd)	1,208	956	26	%	1,210	967	25	%
Condensate and LPG (boed)	Condensate and LPG (boed)	7,060	9,537	(26)	%	8,113	9,382	(14)	%	Condensate and LPG (boed)	8,264	7,060	17	%	7,896	8,113	(3)	%

Table of Contents

Market Conditions

Commodity prices are the most significant factor impacting our revenues, profitability, operating cash flows, the amount of capital we invest in our business, redemption of our debt, payment of dividends and funding of share repurchases. C ~~Following the initial COVID outbreak in 2020, commodity~~ommodity prices ~~steadily increased due to rising oil demand as global economic activity recovered. However, more recently in 2022, commodity prices have~~ experienced significant volatility ~~due to geopolitical events, including~~ in 2022 and this has continued into the third quarter of 2023. Russia’s invasion of Ukraine was a geopolitical shock that caused energy prices to spike significantly higher in early to mid-2022. However, Russian oil production has remained at higher levels than expected, European gas shortages were averted as record levels of LNG were imported into that market and an exceptionally warm 2022 / 2023 winter in both the U.S. and Europe has refilled gas inventories to multi year highs causing prices to fall back significantly. Recent events in the Middle East have added a further geopolitical risk premium to oil prices and the outlook for that region remains extremely uncertain. Economic headwinds, caused by elevated interest rates as central banks fight inflation, continue to be a threat to energy demand ~~impacts tied to macroeconomic conditions from global inflation. Price~~growth as we move forward. Price volatility was also exacerbated by ongoing OPEC+ petroleum supply limitations ~~COVID related impacts, strategic petroleum reserve releases~~ and economic sanctions involving producer countries. We continue to expect commodity price volatility given the complex global dynamics of supply and demand that exist in the ~~market.~~ market. Refer to Item 1A. Risk Factors in our ~~2021~~2022 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 third quarter and first nine months of ~~2022~~2023 and ~~2021.~~2022.


		Three Months Ended September 30,						Nine Months Ended September 30,							Three Months Ended September 30,						Nine Months Ended September 30,
		2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)			2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
Average Price Realizations(a)	Average Price Realizations(a)													Average Price Realizations(a)
Crude oil and condensate (per bbl)(b)	Crude oil and condensate (per bbl)(b)	$	93.67	$	69.40	35	%	$	99.28	$	63.16	57	%	Crude oil and condensate (per bbl)(b)	$	80.90	$	93.67	(14)	%	$	76.13	$	99.28	(23)	%
Natural gas liquids (per bbl)~~(c)~~	Natural gas liquids (per bbl)~~(c)~~	34.00		30.68		11	%	37.14		26.50		40	%	Natural gas liquids (per bbl)~~(c)~~	21.37		34.00		(37)	%	21.29		37.14		(43)	%
Natural gas (per mcf)(d)		7.84		4.17		88	%	6.52		4.35		50	%
Natural gas (per mcf)(c)														Natural gas (per mcf)(c)	2.28		7.84		(71)	%	2.38		6.52		(63)	%
Benchmarks	Benchmarks													Benchmarks
WTI crude oil average of daily prices (per bbl)	WTI crude oil average of daily prices (per bbl)	$	91.43	$	70.52	30	%	$	98.25	$	65.04	51	%	WTI crude oil average of daily prices (per bbl)	$	82.22	$	91.43	(10)	%	$	77.28	$	98.25	(21)	%
Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)	Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)	96.12		71.64		34	%	101.71		66.03		54	%	Magellan East Houston (“MEH”) crude oil average of daily prices (per bbl)	84.00		96.12		(13)	%	76.14		101.71		(25)	%
Mont Belvieu NGLs (per bbl)~~(e)~~(d)	Mont Belvieu NGLs (per bbl)~~(e)~~(d)	36.08		32.27		12	%	38.66		27.08		43	%	Mont Belvieu NGLs (per bbl)~~(e)~~(d)	23.13		36.08		(36)	%	22.99		38.66		(41)	%
Henry Hub natural gas settlement date average (per mmbtu)	Henry Hub natural gas settlement date average (per mmbtu)	8.20		4.01		104	%	6.77		3.18		113	%	Henry Hub natural gas settlement date average (per mmbtu)	2.55		8.20		(69)	%	2.69		6.77		(60)	%

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

(b)Inclusion of realized gains (losses) on crude oil derivative instruments would have no impact on average price realizations for the third quarter 2023 and would have decreased average price realizations by $0.85 per bbl ~~and $4.00 per bbl~~ for the third quarter ~~2022 and 2021, respectively.~~2022. Inclusion of realized gains (losses) on crude oil derivative instruments would have no impact on average price realization for the first nine months of 2023 and would have decreased average price realizations by $2.39 per bbl ~~and $4.72 per bbl~~ for the first nine months of ~~2022 and 2021, respectively.~~2022.

(c)Inclusion of realized gains (losses) on NGL derivative instruments would have no impact on average price realizations for the third quarter 2022 and would have decreased average price realizations by $2.25 per bbl for the third quarter 2021. Inclusion of realized gains (losses) on NGL derivative instruments would have no impact on average price realizations for the first nine months of 2022 and would have decreased average price realizations by $1.61 per bbl for the first nine months of 2021.

~~(d)~~Inclusion of realized gains (losses) on natural gas derivative instruments would have minimal impact on average price realizations for the third quarter ~~2022~~ and would have decreased average price realizations by $1.08 per mcf for the third quarter 2021. Inclusion of realized gains (losses) on natural gas derivative instruments would have minimal impact on average price realizations the first nine months of ~~2022~~2023 and ~~2021, respectively.~~2022.

~~(e)~~(d)Bloomberg Finance LLP: Y-grade Mix NGL of 55% ethane, 25% propane, 5% butane, 8% isobutane and 7% natural gasoline.

Crude oil and condensate – Price realizations may differ from benchmarks due to the quality and location of the product.

Natural gas liquids – The majority of our sales volumes are sold at reference to Mont Belvieu prices.

Natural gas – A significant portion of our volumes are sold at bid-week prices, or first-of-month indices relative to our producing areas.

Table of Contents

International (E.G.)

The following table presents our average price realizations and the related benchmark for crude oil for the third quarter and first nine months of ~~2022~~2023 and ~~2021.~~2022.


		Three Months Ended September 30,						Nine Months Ended September 30,							Three Months Ended September 30,						Nine Months Ended September 30,
		2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)			2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
Average Price Realizations	Average Price Realizations													Average Price Realizations
Crude oil and condensate (per bbl)	Crude oil and condensate (per bbl)	$	74.01	$	56.36	31	%	$	72.26	$	51.54	40	%	Crude oil and condensate (per bbl)	$	64.30	$	74.01	(13)	%	$	59.33	$	72.26	(18)	%
Natural gas liquids (per bbl)	Natural gas liquids (per bbl)	1.00		1.00		—	%	1.00		1.00		—	%	Natural gas liquids (per bbl)	1.00		1.00		—	%	1.00		1.00		—	%
Natural gas (per mcf)	Natural gas (per mcf)	0.24		0.24		—	%	0.24		0.24		—	%	Natural gas (per mcf)	0.24		0.24		—	%	0.24		0.24		—	%
Benchmark	Benchmark													Benchmark
Brent (Europe) crude oil (per bbl)(a)	Brent (Europe) crude oil (per bbl)(a)	$	100.71	$	73.47	37	%	$	104.85	$	67.71	55	%	Brent (Europe) crude oil (per bbl)(a)	$	86.66	$	100.71	(14)	%	$	82.05	$	104.85	(22)	%

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

Crude oil and condensate – Alba field liquids production is primarily condensate. ~~MEGPL and Marathon E.G. International Limited~~We generally sell ~~their~~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 ~~secondary~~ condensate which is then sold by Alba Plant LLC at market prices, with our share of the revenue reflected in income from equity method investments on the consolidated statements of income. Alba Plant LLC delivers the processed dry natural gas to the Alba Unit Parties for distribution and sale to AMPCO and EG LNG.

Natural gas liquids – 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 – Dry natural gas, processed by Alba Plant LLC on behalf of the Alba Unit Parties, is sold by the Alba field to EG LNG and AMPCO at fixed-price ~~long-term~~ contracts resulting in realized prices not tracking market price. The gas sales contracts between Alba Unit and EG LNG and AMPCO expire on December 31, 2023 and in 2026, respectively. We derive additional value from the equity investment in our downstream gas processing units EG LNG and AMPCO. EG LNG sells LNG on a market-based ~~long-term~~ contract and AMPCO markets methanol at market prices.

In March 2023, we announced the signing of a HOA to progress the development of the Equatorial Guinea Regional Gas Mega Hub. 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 is 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 to processing Alba Unit gas, Alba Plant LLC and EG LNG process ~~third party~~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.

Table of Contents

Results of Operations

Three Months Ended September 30, ~~2022~~2023 vs. Three Months Ended September 30, ~~2021~~2022

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


		Three Months Ended September 30,					Three Months Ended September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
Revenues from contracts with customers	Revenues from contracts with customers					Revenues from contracts with customers
United States	United States	$	1,927	$	1,375	United States	$	1,700	$	1,927
International	International	81		63		International	71		81
Segment revenues from contracts with customers	Segment revenues from contracts with customers	$	2,008	$	1,438	Segment revenues from contracts with customers	$	1,771	$	2,008

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									Increase (Decrease) Related to
(In millions)	(In millions)	Three Months Ended September 30, 2021		Price Realizations		Net Sales Volumes		Three Months Ended September 30, 2022		(In millions)	Three Months Ended September 30, 2022		Price Realizations		Net Sales Volumes		Three Months Ended September 30, 2023
United States Price/Volume Analysis	United States Price/Volume Analysis									United States Price/Volume Analysis
Crude oil and condensate	Crude oil and condensate	$	984	$	370	$	74	$	1,428	Crude oil and condensate	$	1,428	$	(223)	$	203	$	1,408
Natural gas liquids	Natural gas liquids	183		21		12		216		Natural gas liquids	216		(105)		66		177
Natural gas	Natural gas	144		122		(5)		261		Natural gas	261		(276)		127		112
Other sales		64						22
Other sales(a)										Other sales(a)	22						3
Total	Total	$	1,375					$	1,927	Total	$	1,927					$	1,700
International Price/Volume Analysis	International Price/Volume Analysis									International Price/Volume Analysis
Crude oil and condensate	Crude oil and condensate	$	56	$	19	$	—	$	75	Crude oil and condensate	$	75	$	(10)	$	(1)	$	64
Natural gas liquids	Natural gas liquids	—		1		—		1		Natural gas liquids	1		—		—		1
Natural gas	Natural gas	6		—		(1)		5		Natural gas	5		—		—		5
Other sales	Other sales	1						—		Other sales	—						1
Total	Total	$	63					$	81	Total	$	81					$	71

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

Net gain ~~(loss)~~ on commodity derivatives in the third quarter of ~~2022,~~2023 was ~~a gain of $41~~$1 million, compared to a net ~~loss~~gain of ~~$79~~$41 million for the same period in ~~2021.~~2022. We have ~~multiple crude oil, natural gas and NGL~~commodity derivative contracts ~~that~~which settle against ~~various indices.~~the NYMEX WTI and Henry Hub indexes. We record commodity derivative gains/losses as the index pricing and forward curves change each period. See Note 1312 to the consolidated financial statements for further information.

Income from equity method investments ~~increased $104 million in third quarter of 2022. Our investees benefited from higher price realizations in 2022.~~

~~Production expenses~~ ~~increased $62~~decreased $152 million in the third quarter of 2023, when compared to the third quarter of 2022, ~~versus~~primarily due to lower prices realized by our equity method investees during the third quarter of 2023.

Production expenses for the third quarter of 2023 decreased by $1 million compared to the same period in ~~2021, primarily~~2022. In the Eagle Ford, production expenses increased when compared to the prior year as a result of our acquisition of the ~~U.S. segment’s higher~~Eagle Ford assets of Ensign in December 2022 and inflationary pressures. However, this increase was offset by decreased expenses in other areas as a result of less workover activity and ~~inflationary pressures on labor, fuel, chemicals and services.~~expense projects when compared to the same period in 2022.

The following table provides production expense and production expense rates ~~(expense per boe)~~ for each segment:


		Three Months Ended September 30,													Three Months Ended September 30,
($ in millions; rate in $ per boe)	($ in millions; rate in $ per boe)	2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)		($ in millions; rate in $ per boe)	2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
Production Expense and Rate	Production Expense and Rate	Expense						Rate						Production Expense and Rate	Expense						Rate
United States	United States	$	173	$	119	45	%	$	6.40	$	4.59	39	%	United States	$	173	$	173	—	%	$	5.07	$	6.40	(21)	%
International	International	$	20	$	12	67	%	$	3.55	$	2.17	64	%	International	$	19	$	20	(5)	%	$	3.99	$	3.55	12	%

Table of Contents

Shipping, handling and other operating expensesdecreased ~~$20~~$35 million in the third quarter of ~~2022 versus~~2023 when compared to the same period in ~~2021,~~2022, primarily due to lower legal costs and a decrease in purchases of commodity volumes for resale ~~(used~~ to satisfy transportation ~~commitments)~~commitments as compared to the prior ~~period.~~period, partially offset by an increase in shipping and handling costs due to increased volumes from our acquisition of the Eagle Ford assets of Ensign in December 2022.

Exploration expenses include unproved property impairments, dry well costs, geological and geophysical and other costs. The decrease in exploration expenses was primarily driven by lower impairments of unproved property leases and lower dry well costs in the third quarter of 2023 when compared the same period of 2022, ~~includes the write-off of drilled~~primarily due to dry well costs and ~~uncompleted exploratory wells, primarily~~unproved property impairments in Louisiana Austin ~~Chalk.~~Chalk in the third quarter of 2022. See Note 5 to the consolidated financial statements for further information.

The following table summarizes the components of exploration expenses:


		Three Months Ended September 30,							Three Months Ended September 30,
(In millions)	(In millions)	2022		2021		Increase (Decrease)		(In millions)	2023		2022		Increase (Decrease)
Exploration Expenses	Exploration Expenses							Exploration Expenses
Unproved property impairments	Unproved property impairments	$	45	$	48	(6)	%	Unproved property impairments	$	16	$	45	(64)	%
Dry well costs	Dry well costs	26		14		86	%	Dry well costs	2		26		(92)	%
Geological, geophysical and other								Geological, geophysical and other	2		2		—	%

Other		2		1		100	%
Total exploration expenses	Total exploration expenses	$	73	$	63	16	%	Total exploration expenses	$	20	$	73	(73)	%

Depreciation, depletion and amortization ~~decreased $62~~increased $123 million in the third quarter of ~~2022~~2023 primarily as a result of ~~lower DD&A (expense per boe) rate impacted by field-level changes in reserves. In addition, the DD&A rate is impacted by capitalized costs and the sales volume mix between fields.~~higher production volumes.

Our segments apply the units-of-production method to the majority of assets, including capitalized asset retirement costs; therefore, volumes have an impact on DD&A expense. The following table provides DD&A expense and DD&A expense rates for each segment:


		Three Months Ended September 30,													Three Months Ended September 30,
($ in millions; rate in $ per boe)	($ in millions; rate in $ per boe)	2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)		($ in millions; rate in $ per boe)	2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
DD&A Expense and Rate	DD&A Expense and Rate	Expense						Rate						DD&A Expense and Rate	Expense						Rate
United States	United States	$	441	$	499	(12)	%	$	16.20	$	19.29	(16)	%	United States	$	570	$	441	29	%	$	16.74	$	16.20	3	%
International	International	$	14	$	17	(18)	%	$	2.82	$	3.12	(10)	%	International	$	12	$	14	(14)	%	$	2.39	$	2.82	(15)	%

~~Loss on early extinguishment of debt~~ ~~decreased $102 million~~2023 primarily due to ~~make-whole call provisions paid upon redemption of $900 million in senior unsecured notes~~lower sales revenue in the third quarter of ~~2021. See~~ ~~Note 15~~2023, when compared to the ~~consolidated financial statements for further detail.~~same period in 2022.

Net interest and other increased $42 million in the third quarter of 2023 primarily as a result of increased interest expense associated with borrowings on our Term Loan Facility and Revolving Credit Facility.

Provision for income taxes ~~reflects an effective income tax rate of 23%~~decreased $113 million in the third quarter of ~~2022, as~~2023 primarily due to a decrease in income before income taxes for the current quarter when compared to ~~an effective income tax rate of 2%~~the same period in ~~the third quarter of 2021. See~~ ~~Note 6~~ ~~to the consolidated financial statements for a more detailed discussion concerning the changes in the effective tax rate.~~2022.

Table of Contents

Segment Income

Segment income represents income that excludes certain items not allocated to our operating segments, net of income taxes. ~~A portion of our corporate and operations general and administrative support costs are~~See Note 5 to the consolidated financial statements for further details regarding items not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, goodwill and equity method investments, changes in our valuation allowance, unrealized gains or losses on commodity and interest rate derivative instruments, effects of pension settlements and curtailments or other items (as determined by the chief operating decision maker (“CODM”)) are not allocated to operating segments.

The following table reconciles segment income to net income:


		Three Months Ended September 30,				Three Months Ended September 30,
(In millions)	(In millions)	2022		2021			(In millions)	2023		2022
United States	United States	$	723	$	305		United States	$	505	$	723
International	International	181		93			International	62		181
Segment income	Segment income	904		398			Segment income	567		904
Items not allocated to segments, net of income taxes	Items not allocated to segments, net of income taxes	(87)		(214)			Items not allocated to segments, net of income taxes	(114)		(87)
Net income	Net income	$	817	$	184		Net income	$	453	$	817

United States segment income in the third quarter of ~~2022~~2023 was $~~723~~505 million of income versus ~~$305~~$723 million of income for the same period in ~~2021.~~2022. The ~~increase~~decrease in segment income ~~was primarily due to higher price realizations and lower realized commodity derivative losses, partially offset by higher income taxes, production taxes and production expense in~~is a result of the ~~third quarter of 2022.~~variances described above.

International segment income in the third quarter of ~~2022~~2023 was $~~181~~62 million of income versus ~~$93~~$181 million of income for the same period in ~~2021,~~2022. The decrease was primarily due to ~~higher~~lower prices realized by our equity method investees.

Items not allocated to segments, net of income taxes in the third quarter of ~~2022~~2023 was a loss of ~~$87~~$114 million versus a loss of ~~$214~~$87 million for the same period in ~~2021,~~2022. The increase in loss was primarily due to ~~higher costs~~unrealized net losses on commodity derivatives in the ~~prior period for the extinguishment~~third quarter of ~~debt and an increase in~~2023 versus unrealized net gains on commodity derivatives in the ~~third quarter~~same period of ~~2022.~~2022, partially offset by lower exploration expenses in 2023, as well as higher interest expense as a result of outstanding borrowings on our Term Loan Facility and Revolving Credit Facility.

Results of Operations

Nine Months Ended September 30, ~~2022~~2023 vs. Nine Months Ended September 30, ~~2021~~2022

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


		Nine Months Ended September 30,						Nine Months Ended September 30,
(In millions)	(In millions)		2022		2021		(In millions)		2023		2022
Revenues from contracts with customers	Revenues from contracts with customers						Revenues from contracts with customers
United States	United States		$	5,730	$	3,696	United States		$	4,643	$	5,730
International	International		207		173		International		179		207
Segment revenues from contracts with customers	Segment revenues from contracts with customers		$	5,937	$	3,869	Segment revenues from contracts with customers		$	4,822	$	5,937

Table of Contents

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									Increase (Decrease) Related to
(In millions)	(In millions)	Nine Months Ended September 30, 2021		Price Realizations		Net Sales Volumes		Nine Months Ended September 30, 2022		(In millions)	Nine Months Ended September 30, 2022		Price Realizations		Net Sales Volumes		Nine Months Ended September 30, 2023
United States Price/Volume Analysis	United States Price/Volume Analysis									United States Price/Volume Analysis
Crude oil and condensate	Crude oil and condensate	$	2,711	$	1,580	$	51	$	4,342	Crude oil and condensate	$	4,342	$	(1,152)	$	598	$	3,788
Natural gas liquids	Natural gas liquids	430		192		49		671		Natural gas liquids	671		(374)		205		502
Natural gas	Natural gas	450		213		(23)		640		Natural gas	640		(591)		288		337
Other sales		105						77
Other sales(a)										Other sales(a)	77						16
Total	Total	$	3,696					$	5,730	Total	$	5,730					$	4,643
International Price/Volume Analysis	International Price/Volume Analysis									International Price/Volume Analysis
Crude oil and condensate	Crude oil and condensate	$	151	$	53	$	(18)	$	186	Crude oil and condensate	$	186	$	(35)	$	9	$	160
Natural gas liquids	Natural gas liquids	2		—		—		2		Natural gas liquids	2		—		—		2
Natural gas	Natural gas	18		—		(1)		17		Natural gas	17		—		(3)		14
Other sales	Other sales	2						2		Other sales	2						3
Total	Total	$	173					$	207	Total	$	207					$	179

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

Net ~~loss~~gain (loss) on commodity derivatives ~~decreased $269~~in the first nine months of 2023 was a net gain of $19 million, ~~when~~ compared to a net loss of $129 million for the same period in ~~2021.~~2022. We have ~~multiple crude oil, natural gas and NGL~~commodity derivative contracts that settle against ~~various indices.~~the NYMEX WTI and Henry Hub indexes. We record commodity derivative gains/losses as the index pricing and forward curves change each period. See Note 1312 to the consolidated financial statements for further information.

Income from equity method investments ~~increased $290~~decreased $329 million for the first nine months of ~~2022. Our~~2023, primarily as a result of lower prices realized by our equity method investees ~~benefited from higher price realizations in~~during the first nine months of ~~2022.~~2023.

Production expenses for the first nine months of ~~2022~~2023 increased by ~~$131~~$98 million compared to the same period in ~~2021,~~2022, primarily as a result of our acquisition of the ~~U.S. segment’s higher workover activity~~Eagle Ford assets of Ensign in December 2022 and inflationary pressures, ~~on labor, fuel, chemicals and services.~~when compared to the same period of 2022. In addition, in our International segment, production expenses were higher due to the triennial turnaround in April.

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


		Nine Months Ended September 30,													Nine Months Ended September 30,
($ in millions; rate in $ per boe)	($ in millions; rate in $ per boe)	2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)		($ in millions; rate in $ per boe)	2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
Production Expense and Rate	Production Expense and Rate	Expense						Rate						Production Expense and Rate	Expense						Rate
United States	United States	$	464	$	343	35	%	$	5.94	$	4.49	32	%	United States	$	542	$	464	17	%	$	5.58	$	5.94	(6)	%
International	International	$	45	$	35	29	%	$	2.76	$	2.00	38	%	International	$	65	$	45	44	%	$	4.69	$	2.76	70	%

Shipping, handling and other operating expenses~~increased$37~~decreased $88 million in the first nine months of 2023, when compared to the same period in 2022, ~~from~~primarily due to a decrease in purchases of commodity volumes for resale to satisfy transportation commitments and lower legal costs as compared to the ~~comparable 2021 period. As disclosed in our Form 10-K, certain of our processing arrangements with midstream entities are percentage-of-proceeds contracts. We classify the proceeds retained~~prior period, partially offset by ~~the midstream companies as shipping and handling costs. The~~an increase in shipping and handling costs due to increased volumes from our acquisition of ~~these percentage-of-proceeds contracts coincides with~~ the ~~increase~~Eagle Ford assets of Ensign in ~~realized natural gas liquids prices. In addition, we have experienced an increase in legal costs from the comparable 2021 period.~~December 2022.

Exploration expenses include unproved property impairments, dry well costs, geological and geophysical and other costs. The decrease in exploration expenses was primarily driven by lower ~~impairment~~impairments of unproved property leases ~~partially offset by higher~~and lower dry well costs ~~associated with~~in the ~~write-off~~first nine months of ~~drilled~~2023, when compared to the same period in 2022, primarily due to dry well costs and ~~uncompleted exploratory wells, primarily~~unproved property impairments in Louisiana Austin ~~Chalk.~~Chalk in the first nine months of 2022. See Note 5 to the consolidated financial statements for further information.

Table of Contents

The following table summarizes the components of exploration expenses:


		Nine Months Ended September 30,							Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		Increase (Decrease)		(In millions)	2023		2022		Increase (Decrease)
Exploration Expenses	Exploration Expenses							Exploration Expenses
Unproved property impairments	Unproved property impairments	$	59	$	85	(31)	%	Unproved property impairments	$	29	$	59	(51)	%
Dry well costs	Dry well costs	26		16		63	%	Dry well costs	12		26		(54)	%
Geological and geophysical		1		3		(67)	%
Other		6		5		20	%
Geological, geophysical and other								Geological, geophysical and other	5		7		(29)	%

Total exploration expenses	Total exploration expenses	$	92	$	109	(16)	%	Total exploration expenses	$	46	$	92	(50)	%

Depreciation, depletion and amortization ~~decreased $231~~increased $343 million in the first nine months of ~~2022~~2023 primarily as a result of ~~lower DD&A (expense per boe) rate impacted by field-level changes in reserves. In addition, the DD&A rate is impacted by capitalized costs and the sales volume mix between fields.~~higher production volumes.

Our segments apply the units-of-production method to the majority of their assets, including capitalized asset retirement costs; therefore volumes have an impact on DD&A expense. The following table provides DD&A expense and DD&A expense rates for each segment:

Nine Months Ended September 30,
($ in millions; rate in $ per boe) 2022 2021 Increase (Decrease) 2022 2021 Increase (Decrease)
DD&A Expense and Rate Expense Rate
United States $ 1,260 $ 1,477 (15) % $ 16.11 $ 19.33 (17) %
International $ 45 $ 54 (17) % $ 2.80 $ 3.10 (10) %

~~Impairments~~ decreased $56 million in the first nine months of 2022. Impairments in 2021 included a $30 million impairment related to an increase in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico and a $24 million impairment as we decommissioned certain Eagle Ford central facilities. See ~~Note 10~~ ~~to the consolidated financial statements for discussion of the impairments in further detail.~~


	Nine Months Ended September 30,
($ in millions; rate in $ per boe)	2023		2022		Increase (Decrease)		2023		2022		Increase (Decrease)
DD&A Expense and Rate	Expense						Rate
United States	$	1,622	$	1,260	29	%	$	16.70	$	16.11	4	%
International	$	34	$	45	(24)	%	$	2.40	$	2.80	(14)	%

Taxes other than income include production, severance and ad valorem taxes, primarily in the U.S., which tend to increase or decrease in relation to revenue and sales volumes. Taxes other than income ~~increased $145~~decreased $130 million primarily due to ~~higher price realizations in the U.S. segment~~lower sales revenue in the first nine months of ~~2022.~~2023, as well as a nonrecurring Eagle Ford severance tax refund of $47 million related to prior years recorded in June 2023.

~~Loss on early extinguishment of debt~~Net interest and other ~~decreased $121~~increased $140 million ~~due to make-whole call provisions paid upon redemption of our $500 million 2022 Notes~~ in the ~~second quarter~~first nine months of ~~2021~~2023 primarily as a result of increased interest expense associated with borrowings on our Term Loan Facility and ~~our $900 million 2025 Notes in the third quarter of 2021. See~~ ~~Note 15~~ ~~to the consolidated financial statements for further detail.~~Revolving Credit Facility.

Provision for income taxes reflects an effective income tax rate of 21% in the first nine months of 2023. The provision for ~~current year includes~~income taxes in the first nine months of 2022 included a non-cash tax benefit of $685 million arising from the partial release of a valuation allowance on certain U.S. and state deferred tax assets, ~~in first quarter of 2022. This~~which was fully offset by the provision related to ~~current year~~ income earned by our ~~operations.~~operations in the first nine months of 2022. See Note 6 to the consolidated financial statements for ~~a more detailed discussion concerning the rate changes.~~further information.

Segment Income

The following table reconciles segment income to net income:


		Nine Months Ended September 30,					Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
United States	United States	$	2,230	$	724	United States	$	1,295	$	2,230
International	International	456		211		International	181		456
Segment income	Segment income	2,686		935		Segment income	1,476		2,686
Items not allocated to segments, net of income taxes	Items not allocated to segments, net of income taxes	401		(638)		Items not allocated to segments, net of income taxes	(319)		401
Net income	Net income	$	3,087	$	297	Net income	$	1,157	$	3,087

United States segment income for the first nine months of ~~2022~~2023 was ~~$2,230 million~~$1.3 billion of income versus ~~a $724 million~~$2.2 billion of income for the same period in ~~2021. This increase was primarily due to higher price realizations and lower DD&A expenses. These favorable changes were partially offset by higher~~2022. The decrease in segment income ~~taxes, production taxes and production expense in~~is a result of the ~~first nine months~~variances described above.

Table of ~~2022.~~Contents

International segment income for the first nine months of ~~2022~~2023 was ~~$456~~$181 million of income versus ~~$211~~$456 million of income for the same period in ~~2021,~~2022. The decrease was primarily due to ~~higher~~lower prices realized by our equity method investees.

Items not allocated to segments, net of income taxes for the first nine months of ~~2022~~2023 was a loss of $319 million versus $401 million of income ~~versus a $638 million loss~~ for the same period in ~~2021.~~2022. The ~~increase~~change from income to loss was primarily due to the ~~first quarter 2022~~partial release of ~~the~~a valuation allowance on certain U.S. and state deferred tax assets ~~resulting~~in the first six months of 2022, which resulted in a non-cash deferred tax benefit of $685 million. In addition, ~~compared to the same period~~ in ~~2021, net unrealized losses on commodity derivatives decreased by $126 million, and current year~~first nine months of 2023, our interest expense ~~not allocated to segments is lower by $121 million~~increased as a result of ~~debt extinguishment costs recognized in the prior year.~~outstanding borrowings on our Term Loan Facility and Revolving Credit Facility.

Critical Accounting Estimates

~~Other than the item set forth below, there~~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, ~~2021.~~2022.

~~Income Taxes~~

We have recorded deferred tax assets and liabilities, measured at enacted tax rates, for temporary differences between book basis and tax basis, tax credit carryforwards and operating loss carryforwards. In accordance with U.S. GAAP, we routinely assess the realizability of our deferred tax assets and reduce such assets to the expected realizable amount by a valuation allowance if it is more likely than not that some portion or all of the deferred tax assets will not be realized. In assessing the need for additional or adjustments to existing valuation allowances, we consider all available positive and negative evidence. Positive evidence includes reversals of temporary differences, forecasts of future taxable income, assessment of future business assumptions and applicable tax planning strategies that are prudent and feasible. Negative evidence includes losses in recent years as well as the forecasts of future losses in the realizable period. In making our assessment regarding valuation allowances, we weight the evidence based on objectivity.

We base our future taxable income estimates on projected financial information which we believe to be reasonably likely to occur. Numerous judgments and assumptions are inherent in the estimation of future taxable income, including factors such as future operating conditions and the assessment of the effects of foreign taxes on our U.S. federal income taxes. Future operating conditions can be affected by numerous factors, including (i) future crude oil and condensate, NGLs and natural gas prices, (ii) estimated quantities of crude oil and condensate, NGLs and natural gas, (iii) expected timing of production, and (iv) future capital requirements. An estimate of the sensitivity to changes in assumptions resulting in future taxable income calculations is not practicable, given the numerous assumptions that can materially affect our estimates. Unfavorable adjustments to some of the above listed assumptions would likely be offset by favorable adjustments in other assumptions. For example, the impact of sustained reduced commodity prices on future taxable income would likely be partially offset by lower capital expenditures.

Based on the assumptions and judgments described above, during the first quarter of 2022, we re-evaluated the realizability of U.S. and state deferred tax assets and determined that a valuation allowance against certain deferred tax assets was no longer necessary. As such, we recorded a non-cash deferred tax benefit in the first quarter of 2022 for $685 million. See ~~Note 6~~ ~~to the consolidated financial statements for further detail.~~

~~Accounting Standards Not Yet Adopted~~

~~See~~ ~~Note 2~~ ~~to the consolidated financial statements.~~

Cash Flows

Commodity prices are the most significant factor impacting our revenues, profitability, operating cash flows, the amount of capital we invest in our business, principal debt repayments, payment of dividends and funding of share repurchases. We generated significant positive cash flow from operations during the first nine months of 2022. We continue to expect volatility in commodity prices and that could impact the amount of cash flow from operations we generate. The following table presents sources and uses of cash and cash equivalents:


		Nine Months Ended September 30,					Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
Sources of cash and cash equivalents	Sources of cash and cash equivalents					Sources of cash and cash equivalents
Operating activities		$	4,301	$	2,093

Disposal of assets, net of cash transferred to the buyer		8		29
Net cash provided by operating activities						Net cash provided by operating activities	$	3,007	$	4,301
Proceeds from revolving credit facility						Proceeds from revolving credit facility	1,018		—
Proceeds from commercial paper borrowings, net						Proceeds from commercial paper borrowings, net	450		—
Borrowings(a)						Borrowings(a)	200		—
Equity method investments - return of capital						Equity method investments - return of capital	57		12
Other	Other	29		15		Other	—		23
Total sources of cash and cash equivalents	Total sources of cash and cash equivalents	$	4,338	$	2,137	Total sources of cash and cash equivalents	$	4,732	$	4,336
Uses of cash and cash equivalents	Uses of cash and cash equivalents					Uses of cash and cash equivalents
Additions to property, plant and equipment	Additions to property, plant and equipment	$	(1,117)	$	(772)	Additions to property, plant and equipment	$	(1,659)	$	(1,117)

Debt repayment		(35)		(1,400)
Debt extinguishment costs		—		(117)
Repayments of revolving credit facility						Repayments of revolving credit facility	(1,468)		—
Shares repurchased under buyback programs	Shares repurchased under buyback programs	(2,474)		—		Shares repurchased under buyback programs	(1,121)		(2,474)
Debt repayments(a)						Debt repayments(a)	(401)		(35)

Dividends paid	Dividends paid	(162)		(94)		Dividends paid	(186)		(162)
Purchases of shares for tax withholding obligations	Purchases of shares for tax withholding obligations	(21)		(10)		Purchases of shares for tax withholding obligations	(31)		(21)
Acquisitions, net of cash acquired						Acquisitions, net of cash acquired	(15)		2
Other	Other	—		(1)		Other	(11)		—
Total uses of cash and cash equivalents	Total uses of cash and cash equivalents	$	(3,809)	$	(2,394)	Total uses of cash and cash equivalents	$	(4,892)	$	(3,807)

(a)Includes repayment and new borrowing associated with April 2023 remarketing to investors of $200 million sub-series 2017A-1 bonds. See Note 14 to the consolidated financial statements for further information.

Sources of cash and cash equivalents

Cash flows generated from operating activities during the third quarter of 2023 were 30% lower compared to 2022, primarily as a result of lower realized commodity prices, partially offset by higher volumes resulting from our acquisition of the Eagle Ford assets of Ensign in December 2022.

During the first nine months of ~~2022 were significantly higher compared~~2023, we borrowed $1.0 billion and repaid $1.5 billion under our Revolving Credit Facility. Additionally, we have net outstanding commercial paper borrowings of $450 million as of September 30, 2023. See the Liquidity and Capital Resources section below for further information.

Table of Contents

Uses of cash and cash equivalents

During the first nine months of 2023, we repurchased approximately 45 million shares of our common stock pursuant to the ~~same period in 2021, primarily as~~share repurchase program at a ~~result~~cost of ~~higher realized commodity prices.~~$1.1 billion, paid dividends of $186 million and repaid the $70 million 8.5% Senior Notes and $131 million 8.125% Senior Notes. Additionally, we repurchased $31 million of shares during the first nine months of 2023 related to our tax withholding obligations associated with the vesting of stock-based compensation awards; these repurchases do not impact our share repurchase program authorization.

During the third quarter of 2023, we utilized commercial paper borrowings to fully repay our $450 million outstanding borrowings against our $2.6 billion unsecured Revolving Credit Facility. See Note 14 to the consolidated financial statements for further information.

The following table shows capital expenditures by segment and reconciles to additions to property, plant and equipment as presented in the consolidated statements of cash flows:


		Nine Months Ended September 30,					Nine Months Ended September 30,
(In millions)	(In millions)	2022		2021		(In millions)	2023		2022
United States	United States	$	1,124	$	770	United States	$	1,661	$	1,124
International	International	1		4		International	3		1
Corporate		11		7
Not Allocated to Segments (Corporate)						Not Allocated to Segments (Corporate)	9		11
Total capital expenditures (accrued)	Total capital expenditures (accrued)	1,136		781		Total capital expenditures (accrued)	1,673		1,136
Change in capital expenditure accrual	Change in capital expenditure accrual	(19)		(9)		Change in capital expenditure accrual	(14)		(19)
Total use of cash and cash equivalents for property, plant and equipment	Total use of cash and cash equivalents for property, plant and equipment	$	1,117	$	772	Total use of cash and cash equivalents for property, plant and equipment	$	1,659	$	1,117

The increase in our capital expenditures for the U.S. segment in the first nine months of ~~2022~~2023 compared to the same period in ~~2021~~2022 was largely ~~reflects~~driven by increased investment and drilling related to the Eagle Ford acreage we acquired from Ensign in December 2022. Additionally, inflationary pressures related to oil field services, labor, drilling materials and equipment ~~as well as differences~~ in ~~timing~~the first nine months of ~~activities~~2023, compared to the same period in ~~our drilling and completion program.~~2022, contributed to the increase in capital expenditures.

Liquidity and Capital Resources

Capital Resources and Available Liquidity

Our main sources of liquidity are cash and cash equivalents, internally generated cash flow from operations, ~~sales of non-core assets,~~ capital market transactions and our ~~revolving~~Revolving Credit Facility. During the second quarter of 2023, we obtained ratings for our commercial paper from Moody’s, Standard & Poor’s and Fitch. Pursuant to our 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. At September 30, ~~2022,~~2023, we had approximately ~~$3.6~~$2.3 billion of liquidity consisting of ~~$1.1 billion~~$174 million in cash and cash equivalents and ~~$2.5~~$2.1 billion available under our ~~revolving~~Revolving Credit Facility. On July 28, 2022, we executed the seventh amendment to our Credit Facility. The primary changes to the Credit Facility effected by this amendment were to (i) extend the maturity date of the Credit Facility by three years to July 28, 2027, (ii) decrease the size of the Credit Facility from $3.1 billion to $2.5 billion, (iii) replace the LIBOR interest rate benchmark with the secured overnight financing rate (“SOFR”) and (iv) implement certain revisions to the Pricing Schedule.

Our working capital requirements are supported by our cash and cash equivalents, commercial paper program and our Revolving Credit Facility. We may issue commercial paper, draw on our ~~revolving~~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 21 to the consolidated financial statements for further discussion of how our commitments and contingencies could affect our available liquidity. General economic conditions, commodity prices, and financial, business and other factors ~~including the global pandemic,~~ could affect our operations and our ability to access the capital markets.

We ~~continue to be rated~~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, ~~2021~~2022 for a discussion of how a downgrade in our credit ratings could affect us.

~~As discussed~~Table of Contents

We may incur additional debt in ~~Note 23~~ to the consolidated financial statements, on November 2, 2022, we entered into an agreement to acquire approximately 130,000 net proved and unproved acres, with an average 97% working interest, in the Eagle Ford resource play in Texas for total cash consideration of $3.0 billion. We expectorder 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 ~~acquisition using~~risk that our liquidity and financial flexibility deteriorates. See Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2022 for a ~~combination~~further discussion of cash on hand, borrowings on the company’s Credit Facility, and new prepayable debt. The transaction is subject to customary terms and conditions, including closing adjustments, and is expected to close by year-end 2022.how our level of indebtedness could affect us.

Credit Arrangements and Borrowings

In November 2022, we entered into a two-year $1.5 billion Term Loan Facility and borrowed the full amount thereunder in December 2022. The Term Loan Facility can be prepaid without penalty. Subsequent to the quarter, we repaid $250 million of outstanding borrowings on October 31, 2023. We have $1.3 billion in borrowings remaining under our Term Loan Facility.

As of September 30, 2023, we had $5.3 billion of total long-term debt outstanding. Long-term debt due within one year consists of $200 million 2.1% Bonds and $200 million 2.125% Bonds which feature a mandatory put on July 1, 2024. In addition, as of September 30, 2023, we had outstanding commercial paper borrowings of $450 million.

~~Our~~Both our Term Loan Facility and Revolving Credit Facility ~~includes~~include a covenant requiring that our total debt to total capitalization ratio not exceed 65% as of the last day of the fiscal quarter. Our total debt-to-capital ratio was ~~20%~~26% at both September 30, ~~2022~~2023 and December 31, ~~2021.~~2022. See Note 1514 to the consolidated financial statements for further information.

At September 30, 2022, we had no borrowings on our $2.5 billion Credit Facility and $4.0 billion of total long-term debt outstanding, of which $402 million is due within the next year. In May 2022, we redeemed the $32 million 9.375% Senior Notes on the maturity date. Our next significant long-term debt maturity is in the amount of $1.0 billion due 2027. Refer to our ~~2021~~2022 Annual Report on Form 10-K for a listing of our long-term debt maturities.

~~Shelf Registration~~On April 3, 2023, we closed a $200 million remarketing to investors of sub-series 2017A-1 bonds that are part of the $1 billion St. John the Baptist, State of Louisiana revenue refunding bonds Series 2017. The bonds are subject to an interest rate of 4.05% and a mandatory purchase date of July 1, 2026.

Other sources of liquidity

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

Capital Requirements

Share Repurchase Program

~~During the first nine months~~Our Board of ~~2022, we repurchased approximately $2.5 billion of shares of our common stock. The total remaining~~Directors has authorized a share repurchase program. Our remaining authorization ~~was approximately $926 million~~ at September 30, 2022. Additionally, we repurchased $21 million of shares during the first nine months of 2022 related to our tax withholding obligations associated with the vesting of employee restricted stock awards and restricted stock units; these repurchases do not impact our share repurchase program authorization.

2023 was approximately $1.4 billion. Subsequent to the quarter, ~~we repurchased approximately $230 million of shares of our common stock through November 2, 2022. Effective November 2, 2022,~~ our Board of Directors increased our remaining ~~share repurchase program~~ authorization to $2.5 ~~billion.~~billion effective on November 1, 2023.

Dividends

On October ~~26, 2022,~~25, 2023, our Board of Directors approved a dividend of ~~$0.09~~$0.11 per share payable December ~~12, 2022~~11, 2023 to stockholders of record at the close of business on November ~~16,~~15, 2023.

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 do not anticipate being subject to the corporate book minimum tax in 2023 but anticipate that corporate book minimum tax will apply in 2024. The U.S. Treasury is expected to publish further guidance and regulations that will be relevant to scoping considerations and the calculation of minimum income tax liabilities. As this guidance is issued, we will continue to evaluate and assess the impact the IRA may have on our current and future period income taxes.

Other Contractual Cash Obligations

As of September 30, 2023, material changes to our contractual cash obligations compared to December 31, 2022 include the previously discussed repayment of $450 million outstanding borrowings against our $2.6 billion unsecured Revolving Credit Facility, which was due in 2027, and the addition of commercial paper borrowings of $450 million. In addition, we repaid$250 million of outstanding borrowings against our $1.5 billion Term Loan Facility on October 31, 2023.

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 ~~2021~~2022 Annual Report on Form 10-K. ~~Refer to~~ ~~Note 23~~ ~~to the consolidated financial statements for discussion of the recently announced acquisition of Eagle Ford acreage.~~

Table of Contents

Environmental Matters and Other Contingencies

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 ~~2021~~2022 Annual Report on Form 10-K. See Note 2221 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 (the “Exchange Act”). All statements, other than statements of historical fact, including without limitation statements regarding our future performance, business strategy, ~~2022~~ capital budget and allocations, reserve estimates, asset quality, production guidance, drilling plans, capital plans, future debt retirement, cost and expense estimates, asset acquisitions and dispositions, expected impacts of the IRA, tax assumptions and allowances, future financial position, statements regarding future commodity prices, ~~statements regarding the Ensign acquisition and the anticipated timing and benefits thereof, anticipated acquisition financing~~ and statements regarding management’s other plans and objectives for future operations, are forward-looking statements. Words such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,,” “intend,” “may,” “outlook,” “plan,” “positioned,” “project,” “seek,” “should,” “target,” “will,” “would” or similar words may be used to identify forward-looking statements; however, the absence of these words does not mean that the statements are not forward-looking. While we believe that our assumptions concerning future events are reasonable, athese expectations may not prove to be correct. A number of factors could cause results to differ materially from those ~~projected,~~indicated by such forward-looking statements including, but not limited to:

•conditions in the oil and gas industry, including supply and demand levels for crude oil and condensate, NGLs and natural gas and the resulting impact on price;

•changes in expected reserve or production levels;

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

•capital available for exploration and development;

•risks related to our hedging activities;

•voluntary ~~and~~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;

•~~capital available for exploration and development;~~

•~~the inability of any party to satisfy closing conditions or delays in execution with respect to our asset acquisitions and dispositions;~~

•drilling and operating risks;

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

•~~well production timing;~~

•availability of drilling rigs, materials and labor, including the costs associated therewith;

•difficulty in obtaining necessary approvals and permits;

•the availability, cost, terms and timing of issuance or execution of, competition for, and challenges to, mineral licenses and leases and governmental and other permits and rights-of-way, and our ability to retain mineral licenses and leases;

•non-performance by third parties of their contractual ~~or legal~~ obligations, including due to bankruptcy;

•administrative impediments or unexpected events that may impact dividends or other distributions, and the timing thereof, from our equity method investees;

•Table of Contents~~changes in our credit ratings;~~

•unforeseen hazards such as weather conditions, a health pandemic (including COVID-19), acts of war or terrorist acts and the governmental or military response thereto;

•~~shortages~~the impacts of ~~key personnel, including employees, contractors~~supply chain disruptions that began during the COVID-19 pandemic and ~~subcontractors;~~the resulting inflationary environment;

•security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, or breaches of the information technology systems, facilities and infrastructure of third parties with which we transact business;

•~~changes in safety, health, environmental, tax~~our ability to achieve, reach or otherwise meet initiatives, plans or ambitions with respect to ESG matters;

•our ability to pay dividends and ~~other regulations or requirements or initiatives including those addressing~~make share repurchases;

•our ability to secure increased exposure to global LNG market prices and progress on the ~~impact of global climate change, air emissions or water management;~~E.G. Gas Mega Hub;

•impacts of the ~~Inflation Reduction Act of 2022;~~

•~~delay or failure to consummate the Ensign transaction due to unsatisfied closing conditions or otherwise;~~IRA;

•~~changes in the ultimate amount of cash consideration to be paid in the Ensign transaction due to purchase price adjustments or otherwise, and~~ the risk that ~~if acquired,~~ the Ensign assets do not perform consistent with our expectations, including with respect to future production or drilling inventory;

•other geological, operating and economic considerations; and

•the risk factors, forward-looking statements and challenges and uncertainties described in our ~~2021~~2022 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.

4241

Table of Contents

Item 3. Quantitative and Qualitative Disclosures About Market Risk

We are exposed to market risks in the normal course of business including commodity price risk and interest rate risk. We employ various strategies, including the use of financial derivatives to manage the risks related to commodity price and interest rate fluctuations. See Note 1312 and Note 1413 to the consolidated financial statements for detail relating to our open commodity derivative positions, including underlying notional quantities, how they are reported in our consolidated financial statements and how their fair values are measured.

Commodity Price Risk

As of September 30, ~~2022,~~2023, we had ~~various~~ open commodity ~~derivatives.~~derivatives related to crude oil and natural gas. Based on the September 30, ~~2022~~2023 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)	(In millions)	Fair Value at September 30, 2022		Hypothetical Price Increase of 10%		Hypothetical Price Decrease of 10%		(In millions)	Fair Value at September 30, 2023		Hypothetical Price Increase of 10%		Hypothetical Price Decrease of 10%
Derivative asset (liability) - Crude Oil	Derivative asset (liability) - Crude Oil	$	(7)	$	(12)	$	(4)	Derivative asset (liability) - Crude Oil	$	—	$	(13)	$	9
Derivative asset (liability) - Natural Gas	Derivative asset (liability) - Natural Gas	(4)		(8)		—		Derivative asset (liability) - Natural Gas	3		2		3

Total	Total	$	(11)	$	(20)	$	(4)	Total	$	3	$	(11)	$	12

Interest Rate Risk

At September 30, ~~2022,~~2023, our portfolio of current and long-term debt is comprised of floating rate debt and fixed-rate ~~instruments with an~~instruments. Our Term Loan Facility is a floating rate debt instrument, which exposes us to the risk of earnings or cash flow losses as the result of potential increases in market interest rates. At September 30, 2023, we had $1.5 billion outstanding ~~balance~~borrowings under floating rate debt instruments. Assuming no change in the amount of ~~$4.0 billion.~~floating rate debt outstanding, a hypothetical 100 basis point increase in the average interest rate under these borrowings would increase our annual interest expense by approximately $15 million. Actual results may vary due to changes in the amount of floating rate debt outstanding.

At September 30, 2023, we had $3.8 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 September 30, ~~2022,~~2023, we had forward starting interest rate swap agreements with a total notional amount of $295 million designated as cash flow hedges. We utilize cash flow hedges to manage our exposure to interest rate movements by utilizing interest rate swap agreements to hedge variations in cash flows related to the ~~1-month LIBOR~~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 ~~hedge~~hedges to the following as of September 30, ~~2022:~~2023:


(In millions)	(In millions)	Fair Value at September 30, 2022		Hypothetical Interest Rate Increase of 10%		Hypothetical Interest Rate Decrease of 10%		(In millions)	Fair Value at September 30, 2023		Hypothetical Interest Rate Increase of 10%		Hypothetical Interest Rate Decrease of 10%
Interest rate asset (liability) - designated as cash flow hedges	Interest rate asset (liability) - designated as cash flow hedges	$	26	$	31	$	22	Interest rate asset (liability) - designated as cash flow hedges	$	25	$	29	$	22

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 September 30, ~~2022.~~2023.

During the first nine months of ~~2022,~~2023, there were no changes in our internal control over financial reporting that have materially affected, or ~~are~~were reasonably likely to materially affect, our internal control over financial reporting.

4342

Table of Contents

Part II – OTHER INFORMATION

Item 1. Legal Proceedings

~~In January 2020, we~~We have received ~~a Notice of Violation (“NOV”)~~NOV’s from the EPA related to allegations of violations of the Clean Air Act ~~relating~~with respect to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. We continue to actively negotiate a draft consent decree with the EPA and Department of ~~Justice containing certain proposed injunctive terms relating to this enforcement action.~~Justice. The resolution of the enforcement action will likely include monetary sanctions and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. We maintain an accrual for estimated potential monetary sanctions. While we do not believe resolution of this matter will have a material adverse effect on our business or operations. We maintain an accrual for estimated future costs related to this matter regarding actions required to retrofit or replace existing equipment, which we expect to incur over multiple years. Our accrual does not include possible monetary sanctions or costs associated with mitigation projects as we are unable to estimate those amounts. Through the date of this filing,operations, there exists substantial uncertainty as to the ultimate result of this matter and it is reasonably possible the result could be materially different from our expectations and our accrual.

~~In July 2022, the~~

The Company received ~~an NOV~~NOV’s from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 and 2022 over certain of the Company’s oil and gas facilities in New Mexico. The ~~notice involves~~notices involve alleged emission and permitting violations. The Company has initiated discussions with the EPA to resolve these matters. ~~As we are still investigating these allegations,~~At this time, we are unable to estimate the potential loss associated with ~~this matter,~~these matters, however, it is reasonably possible that the resolution of these matters may result in a fine or penalty in excess of $300,000.

~~Marathon Oil has been named in various lawsuits alleging royalty underpayments in our domestic operations. We intend to vigorously defend ourselves against such claims. For instance,~~ Marathon Oil was named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and after plaintiffs lost their attempt to certify a class action, a settlement ~~in principle~~ was reached, subject to court approval. We have accrued for potential liabilities associated with these lawsuits based on currently available information; however, actual losses may exceed our accruals or we could be required to accrue additional amountsand in the ~~future.~~first quarter of 2023 such settlement was approved by the court and paid.

Other than the items set forth above, there have been no significant changes to Item 3. Legal Proceedings in our ~~2021~~2022 Annual Report on Form 10-K. See Note 2221 to the consolidated financial statements included in Part I, Item I for a description of such legal and administrative proceedings and Item 3. Legal Proceedings in our ~~2021~~2022 Annual Report on Form 10-K.

Item 1A. Risk Factors

We are subject to various risks and uncertainties in the course of our business. In addition to the other information set forth in this Quarterly Report on Form 10-Q, the reader should carefully consider the factors discussed in Item 1A. Risk Factors in our ~~2021~~2022 Annual Report on Form 10-K. ~~Other than the risk factor set forth below, there~~There have been no material changes or updates to the risk factors ~~from those listed in Item 1A. Risk Factors~~previously disclosed in our ~~2021~~2022 Annual Report on Form 10-K.

Our sector and the broader US economy have experienced higher than expected inflationary pressures in the first nine months of 2022, related to continued supply chain disruptions, labor shortages and geopolitical instability. Should these conditions persist, it may impact our ability to procure materials and equipment on a cost-effective basis, or at all, and, as a result, our business, results of operations and cash flows could be materially and adversely affected.

Throughout the first nine months of 2022, we have experienced significant increases in the costs of certain materials, including steel, sand and fuel, as a result of availability constraints, supply chain disruption, increased demand, labor shortages associated with a fully employed US labor force, inflation and other factors. Though we incorporated inflationary factors into our 2022 business plan, inflation has outpaced those original assumptions. These challenges are due in large measure to increased demand for oil and gas production driven by the continued economic recovery from the COVID-19 pandemic and more broadly, systemic underinvestment in global oil and gas development. These supply and demand fundamentals have been further aggravated by disruptions in global energy supply caused by multiple geopolitical events, including the ongoing conflict between Russia and Ukraine. We continue to undertake actions and implement plans to strengthen our supply chain to address these pressures and protect the requisite access to commodities and services. Nevertheless, we expect for the foreseeable future to experience supply chain constraints and inflationary pressure on our cost structure. These supply chain constraints and inflationary pressures will likely continue to adversely impact our cost of operations and if we are unable to manage our global supply chain, it may impact our ability to procure materials and equipment in a timely and cost-effective manner, if at all, which could result in reduced margins and production delays and, as a result, our business, financial condition, results of operations and cash flows could be materially and adversely affected.

~~Changes in U.S. and international tax rules and regulations, or interpretations thereof, may materially and adversely affect our cash flows, results of operations and financial condition.~~

We are subject to income- and non-income-based taxes in the United States under federal, state, and local jurisdictions and in the foreign jurisdictions in which we operate. Tax laws, regulations and administrative practices in various jurisdictions may be subject to significant change, with or without advance notice, due to economic, political and other conditions, and significant judgment is required in evaluating and estimating our provision and accruals for these taxes. Our tax liabilities could be affected by numerous factors, such as changes in tax, accounting and other laws, regulations, administrative practices, principles and interpretations, the mix and level of earnings in a given taxing jurisdiction or our ownership or capital structure. For example, on August 16, 2022, the United States enacted the Inflation Reduction Act of 2022 (IRA), which is highly complex, subject to interpretation, and contains significant changes to U.S. tax law including, but not limited to, a corporate minimum tax and a 1% excise tax on stock repurchases. The U.S. Department of the Treasury and the U.S. Internal Revenue Service (IRS) are expected to release regulations and interpretive guidance implementing the legislation contained in the IRA, but the details and timing of such regulations are subject to uncertainty at this time. The tax provisions of the IRA which may apply to us are generally effective in 2023 or later and therefore tax impacts to us in 2022 are expected to be immaterial. However, it is possible that the enactment of changes in the U.S. corporate tax system, including in connection with the IRA, could have a material effect on our consolidated cash taxes in the future.

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 September 30, ~~2022~~2023, of equity securities that are registered by Marathon Oil pursuant to Section 12 of the Securities Exchange Act of ~~1934:~~1934.

Period
Total Number of Shares Purchased(a)
Average Price Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(b)
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(b)
07/01/2022 - 07/31/2022 11,256,188 $ 21.77 11,256,188 $ 1,801,759,039
08/01/2022 - 08/31/2022 10,434,951 $ 23.81 10,415,936 $ 1,553,750,872
09/01/2022 - 09/30/2022 24,417,720 $ 25.73 24,406,892 $ 925,752,032
Total 46,108,859 $ 24.33 46,079,016


Period	Total Number of Shares Purchased(a)	Average Price Paid per Share(b)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(c)	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(b)(c)
07/01/2023 - 07/31/2023	—	$	—	—	$	1,764,769,042
08/01/2023 - 08/31/2023	3,840,870	25.97		3,840,870	1,665,019,129
09/01/2023 - 09/30/2023	11,782,201	26.74		11,782,201	1,350,019,479
Total	15,623,071	$	26.55	15,623,071

(a)~~29,843~~No shares of restricted stock were delivered by employees to Marathon Oil, upon vesting, to satisfy tax withholding requirements.

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

(c)Refer to our ~~2021~~2022 Annual Report on Form 10-K for historical share repurchase program authorizations and repurchase activity through December 31, ~~2021. Effective November 2, 2022, our Board~~2022. As of ~~Directors increased our~~September 30, 2023, we have approximately $1.4 billion of authorization remaining under the share repurchase ~~program authorization to $2.5 billion~~.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 September 30, ~~2022~~2023, were held as treasury stock.

Item 5. Other Information

During the three months ended September 30, 2023,nodirector 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.

Table of Contents

Item 6. Exhibits

Incorporated by Reference
(File No. 001-05153, unless otherwise indicated)
Exhibit Number Exhibit Description Form Exhibit Filing Date
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 February 24, 2016)
10-Q 3.2 8/4/2016
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
Seventh Amendment, dated as of July 28, 2022, to the Amended and Restated Credit Agreement dated as of May 28, 2014, as amended by the First Amendment, dated as of May 5, 2015, the Second Amendment, dated as of June 22, 2017, the Third Amendment, dated as of October 18, 2018, the Fourth Amendment, dated as of September 24, 2019, the Fifth Amendment, dated as of December 4, 2020 and the Sixth Amendment, dated as of June 21, 2021, and as supplemented by the Incremental Commitments Supplement, dated as of March 4, 2016 and Incremental Commitments Supplement, dated as of July 11, 2017, among Marathon Oil Corporation, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, and certain other financial institutions named therein
8-K 10.1 8/2/2022
10.2†*
Marathon Oil Corporation Executive Tax, Estate and Financial Planning Program, Amended and Restated Effective July 27, 2022
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.
† Management contract or compensatory plan or arrangement.

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

Exhibit Number

Exhibit Description

Form

Exhibit

Filing Date

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

3.2

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*

Incremental Commitment Supplement, dated as of September 19, 2023, to the Amended and Restated Credit Agreement dated as of May 28, 2014, as amended by the First Amendment, dated as of May 5, 2015, the Second Amendment, dated as of June 22, 2017, the Third Amendment, dated as of October 18, 2018, the Fourth Amendment, dated as of September 24, 2019, the Fifth Amendment, dated as of December 4, 2020, the Sixth Amendment, dated as of June 21, 2021 and the Seventh Amendment, dated as of July 28, 2022, and as supplemented by the Incremental Commitments Supplement, dated as of March 4, 2016 and Incremental Commitments Supplement, dated as of July 11, 2017, among Marathon Oil Corporation, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, and certain other financial institutions named therein.

10.2†*

Marathon Oil Corporation Executive Tax, Estate and Financial Planning Program, Amended and Restated Effective January 1, 2024

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.

4644

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.


November ~~3, 2022~~2, 2023		MARATHON OIL CORPORATION

	By:	/s/ Rob L. White
		Rob L. White
		Vice President, Controller and Chief Accounting Officer
		(Duly Authorized Officer)

4745


	September 30, 2022				December 31, 2021
Maturity Date	Aggregate Notional Amount (in millions)		Weighted Average, LIBOR		Aggregate Notional Amount (in millions)		Weighted Average, LIBOR

June 1, 2025	$	—	—	%	$	350	0.95	%
September 9, 2026	$	—	—	%	$	25	1.45	%


(In millions)	Ownership as of September 30, 2022	September 30, 2022		December 31, 2021
EGHoldings (a)	56%	$	293	$	148
Alba Plant LLC (b)	52%	142		154
AMPCO (c)	45%	133		148
Total		$	568	$	450


Period	Total Number of Shares Purchased(a)	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(b)	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(b)
07/01/2022 - 07/31/2022	11,256,188	$	21.77	11,256,188	$	1,801,759,039
08/01/2022 - 08/31/2022	10,434,951	$	23.81	10,415,936	$	1,553,750,872
09/01/2022 - 09/30/2022	24,417,720	$	25.73	24,406,892	$	925,752,032
Total	46,108,859	$	24.33	46,079,016