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

Commission File Number: 1-9743

EOG RESOURCES, INC.

(Exact name of registrant as specified in its charter)


Delaware						47-0684736
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

1111 Bagby, Sky Lobby 2, Houston, Texas 77002

(Address of principal executive offices) (Zip Code)

713-651-7000

(Registrant's telephone number, including area code)

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


Title of each class	Trading symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.01 per share	EOG	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 ☒ No ☐

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

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

Large accelerated filer ☒ Accelerated filer ☐ Non-accelerated filer ☐

Smaller reporting company ☐ Emerging growth company ☐

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No ☒

Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date.


Title of each class	Number of shares
Common Stock, par value $0.01 per share	~~587,389,496~~583,149,602	(as of October ~~27, 2022)~~26, 2023)

EOG RESOURCES, INC.

TABLE OF CONTENTS

PART I.

FINANCIAL INFORMATION

Page No.

ITEM 1.

Financial Statements (Unaudited)

Condensed Consolidated Statements of Income and Comprehensive Income - Three Months and Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~2022

Condensed Consolidated Balance Sheets - September 30, ~~2022~~2023 and December 31, ~~2021~~2022

Condensed Consolidated Statements of Stockholders' Equity - Three Months and Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~2022

Condensed Consolidated Statements of Cash Flows - Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~2022

Notes to Condensed Consolidated Financial Statements

ITEM 2.

Management's Discussion and Analysis of Financial Condition and Results of Operations

2321

ITEM 3.

Quantitative and Qualitative Disclosures About Market Risk

4241

ITEM 4.

Controls and Procedures

4241

PART II.

OTHER INFORMATION

ITEM 1.

Legal Proceedings

4342

ITEM 2.

Unregistered Sales of Equity Securities and Use of Proceeds

~~ITEM 4.~~

~~Mine Safety Disclosures~~42

ITEM 5.

ITEM 6.

-2-

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(In Millions, Except Per Share Data)

(Unaudited)


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Operating Revenues and Other	Operating Revenues and Other									Operating Revenues and Other
Crude Oil and Condensate	Crude Oil and Condensate	$	4,109	$	2,929	$	12,697	$	7,879	Crude Oil and Condensate	$	3,717	$	4,109	$	10,151	$	12,697
Natural Gas Liquids	Natural Gas Liquids	693		548		2,151		1,229		Natural Gas Liquids	501		693		1,400		2,151
Natural Gas	Natural Gas	1,235		568		2,951		1,597		Natural Gas	417		1,235		1,268		2,951
Losses on Mark-to-Market Financial Commodity Derivative Contracts		(18)		(494)		(4,215)		(1,288)
Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts										Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts	43		(18)		520		(4,215)
Gathering, Processing and Marketing	Gathering, Processing and Marketing	1,561		1,186		5,199		3,056		Gathering, Processing and Marketing	1,478		1,561		4,333		5,199
Gains (Losses) on Asset Dispositions, Net	Gains (Losses) on Asset Dispositions, Net	(21)		1		101		46		Gains (Losses) on Asset Dispositions, Net	35		(21)		95		101
Other, Net	Other, Net	34		27		99		79		Other, Net	21		34		62		99
Total	Total	7,593		4,765		18,983		12,598		Total	6,212		7,593		17,829		18,983
Operating Expenses	Operating Expenses									Operating Expenses
Lease and Well	Lease and Well	335		270		977		810		Lease and Well	369		335		1,076		977
Transportation Costs	Transportation Costs	257		219		729		635		Transportation Costs	240		257		712		729
Gathering and Processing Costs	Gathering and Processing Costs	167		145		463		412		Gathering and Processing Costs	166		167		485		463
Exploration Costs	Exploration Costs	35		44		115		112		Exploration Costs	43		35		140		115
Dry Hole Costs	Dry Hole Costs	18		4		41		28		Dry Hole Costs	—		18		1		41
Impairments	Impairments	94		82		240		170		Impairments	54		94		123		240
Marketing Costs	Marketing Costs	1,621		1,184		5,031		3,013		Marketing Costs	1,383		1,621		4,200		5,031
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	906		927		2,664		2,741		Depreciation, Depletion and Amortization	898		906		2,562		2,664
General and Administrative	General and Administrative	162		142		414		372		General and Administrative	161		162		448		414
Taxes Other Than Income	Taxes Other Than Income	334		277		1,196		731		Taxes Other Than Income	341		334		983		1,196
Total	Total	3,929		3,294		11,870		9,024		Total	3,655		3,929		10,730		11,870
Operating Income	Operating Income	3,664		1,471		7,113		3,574		Operating Income	2,557		3,664		7,099		7,113
Other Income, Net	Other Income, Net	40		6		66		—		Other Income, Net	52		40		168		66
Income Before Interest Expense and Income Taxes	Income Before Interest Expense and Income Taxes	3,704		1,477		7,179		3,574		Income Before Interest Expense and Income Taxes	2,609		3,704		7,267		7,179
Interest Expense, Net	Interest Expense, Net	41		48		137		140		Interest Expense, Net	36		41		113		137
Income Before Income Taxes	Income Before Income Taxes	3,663		1,429		7,042		3,434		Income Before Income Taxes	2,573		3,663		7,154		7,042
Income Tax Provision	Income Tax Provision	809		334		1,560		755		Income Tax Provision	543		809		1,548		1,560
Net Income	Net Income	$	2,854	$	1,095	$	5,482	$	2,679	Net Income	$	2,030	$	2,854	$	5,606	$	5,482
Net Income Per Share	Net Income Per Share									Net Income Per Share
Basic	Basic	$	4.90	$	1.88	$	9.40	$	4.62	Basic	$	3.51	$	4.90	$	9.65	$	9.40
Diluted	Diluted	$	4.86	$	1.88	$	9.34	$	4.59	Diluted	$	3.48	$	4.86	$	9.60	$	9.34
Average Number of Common Shares	Average Number of Common Shares									Average Number of Common Shares
Basic	Basic	583		581		583		580		Basic	579		583		581		583
Diluted	Diluted	587		584		587		584		Diluted	583		587		584		587
Comprehensive Income	Comprehensive Income									Comprehensive Income
Net Income	Net Income	$	2,854	$	1,095	$	5,482	$	2,679	Net Income	$	2,030	$	2,854	$	5,606	$	5,482
Other Comprehensive Income (Loss)
Other Comprehensive Income										Other Comprehensive Income
Foreign Currency Translation Adjustments	Foreign Currency Translation Adjustments	5		2		6		(1)		Foreign Currency Translation Adjustments	2		5		1		6
Other, Net of Tax	Other, Net of Tax	1		—		—		—		Other, Net of Tax	—		1		—		—
Other Comprehensive Income (Loss)		6		2		6		(1)
Other Comprehensive Income										Other Comprehensive Income	2		6		1		6
Comprehensive Income	Comprehensive Income	$	2,860	$	1,097	$	5,488	$	2,678	Comprehensive Income	$	2,032	$	2,860	$	5,607	$	5,488

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

-3-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Millions, Except Share Data)

(Unaudited)


		September 30, 2022		December 31, 2021			September 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and Cash Equivalents	Cash and Cash Equivalents	$	5,272	$	5,209	Cash and Cash Equivalents	$	5,326	$	5,972
Accounts Receivable, Net	Accounts Receivable, Net	3,343		2,335		Accounts Receivable, Net	2,927		2,774
Inventories	Inventories	872		584		Inventories	1,379		1,058
Income Taxes Receivable	Income Taxes Receivable	93		—		Income Taxes Receivable	—		97
Other	Other	621		456		Other	626		574
Total	Total	10,201		8,584		Total	10,258		10,475
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	Oil and Gas Properties (Successful Efforts Method)	67,065		67,644		Oil and Gas Properties (Successful Efforts Method)	70,730		67,322
Other Property, Plant and Equipment	Other Property, Plant and Equipment	4,659		4,753		Other Property, Plant and Equipment	5,355		4,786
Total Property, Plant and Equipment	Total Property, Plant and Equipment	71,724		72,397		Total Property, Plant and Equipment	76,085		72,108
Less: Accumulated Depreciation, Depletion and Amortization	Less: Accumulated Depreciation, Depletion and Amortization	(42,623)		(43,971)		Less: Accumulated Depreciation, Depletion and Amortization	(44,362)		(42,679)
Total Property, Plant and Equipment, Net	Total Property, Plant and Equipment, Net	29,101		28,426		Total Property, Plant and Equipment, Net	31,723		29,429
Deferred Income Taxes	Deferred Income Taxes	18		11		Deferred Income Taxes	33		33
Other Assets	Other Assets	1,167		1,215		Other Assets	1,633		1,434
Total Assets	Total Assets	$	40,487	$	38,236	Total Assets	$	43,647	$	41,371
LIABILITIES AND STOCKHOLDERS' EQUITY	LIABILITIES AND STOCKHOLDERS' EQUITY					LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts Payable	Accounts Payable	$	2,718	$	2,242	Accounts Payable	$	2,464	$	2,532
Accrued Taxes Payable	Accrued Taxes Payable	542		518		Accrued Taxes Payable	605		405
Dividends Payable	Dividends Payable	437		436		Dividends Payable	478		482
Liabilities from Price Risk Management Activities	Liabilities from Price Risk Management Activities	243		269		Liabilities from Price Risk Management Activities	22		169
Current Portion of Long-Term Debt	Current Portion of Long-Term Debt	1,282		37		Current Portion of Long-Term Debt	34		1,283
Current Portion of Operating Lease Liabilities	Current Portion of Operating Lease Liabilities	235		240		Current Portion of Operating Lease Liabilities	337		296
Other	Other	289		300		Other	285		346
Total	Total	5,746		4,042		Total	4,225		5,513

Long-Term Debt	Long-Term Debt	3,802		5,072		Long-Term Debt	3,772		3,795
Other Liabilities	Other Liabilities	2,573		2,193		Other Liabilities	2,698		2,574
Deferred Income Taxes	Deferred Income Taxes	4,517		4,749		Deferred Income Taxes	5,194		4,710
Commitments and Contingencies (Note 8)	Commitments and Contingencies (Note 8)					Commitments and Contingencies (Note 8)

Stockholders' Equity	Stockholders' Equity					Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 587,891,710 Shares Issued at September 30, 2022 and 585,521,512 Shares Issued at December 31, 2021		206		206
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 588,651,638 Shares Issued at September 30, 2023 and 588,396,757 Shares Issued at December 31, 2022						Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 588,651,638 Shares Issued at September 30, 2023 and 588,396,757 Shares Issued at December 31, 2022	206		206
Additional Paid in Capital	Additional Paid in Capital	6,155		6,087		Additional Paid in Capital	6,133		6,187
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss	(6)		(12)		Accumulated Other Comprehensive Loss	(7)		(8)
Retained Earnings	Retained Earnings	17,563		15,919		Retained Earnings	22,047		18,472
Common Stock Held in Treasury, 646,861 Shares at September 30, 2022 and 257,268 Shares at December 31, 2021		(69)		(20)
Common Stock Held in Treasury, 5,602,445 Shares at September 30, 2023 and 700,281 Shares at December 31, 2022						Common Stock Held in Treasury, 5,602,445 Shares at September 30, 2023 and 700,281 Shares at December 31, 2022	(621)		(78)
Total Stockholders' Equity	Total Stockholders' Equity	23,849		22,180		Total Stockholders' Equity	27,758		24,779
Total Liabilities and Stockholders' Equity	Total Liabilities and Stockholders' Equity	$	40,487	$	38,236	Total Liabilities and Stockholders' Equity	$	43,647	$	41,371

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

-4-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Millions, Except Per Share Data)

(Unaudited)


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity			Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at June 30, 2022		$	206	$	6,128	$	(12)	$	16,028	$	(38)	$	22,312
Balance at June 30, 2023														Balance at June 30, 2023	$	206	$	6,257	$	(9)	$	20,497	$	(694)	$	26,257
Net Income	Net Income	—		—		—		2,854		—		2,854		Net Income	—		—		—		2,030		—		2,030
Common Stock Dividends Declared, $2.25 Per Share		—		—		—		(1,319)		—		(1,319)
Common Stock Dividends Declared, $0.825 Per Share														Common Stock Dividends Declared, $0.825 Per Share	—		—		—		(480)		—		(480)
Other Comprehensive Income	Other Comprehensive Income	—		—		6		—		—		6		Other Comprehensive Income	—		—		2		—		—		2
Common Stock Issued Under Stock Plans	Common Stock Issued Under Stock Plans	—		—		—		—		—		—		Common Stock Issued Under Stock Plans	—		—		—		—		—		—
Change in Treasury Stock - Stock Compensation Plans, Net		—		(5)		—		—		(33)		(38)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—		Restricted Stock and Restricted Stock Units, Net	—		(154)		—		—		154		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		34		—		—		—		34		Stock-Based Compensation Expenses	—		57		—		—		—		57
Treasury Stock Issued as Compensation		—		—		—		—		—		—
Balance at September 30, 2022		$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849
Treasury Stock Repurchased														Treasury Stock Repurchased	—		—		—		—		(61)		(61)
Change in Treasury Stock - Stock Compensation Plans, Net														Change in Treasury Stock - Stock Compensation Plans, Net	—		(27)		—		—		(20)		(47)
Balance at September 30, 2023														Balance at September 30, 2023	$	206	$	6,133	$	(7)	$	22,047	$	(621)	$	27,758


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity			Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at June 30, 2021		$	206	$	6,017	$	(15)	$	14,689	$	(16)	$	20,881
Balance at June 30, 2022														Balance at June 30, 2022	$	206	$	6,128	$	(12)	$	16,028	$	(38)	$	22,312
Net Income	Net Income	—		—		—		1,095		—		1,095		Net Income	—		—		—		2,854		—		2,854
Common Stock Dividends Declared, $0.4125 Per Share		—		—		—		(242)		—		(242)
Common Stock Dividends Declared, $2.25 Per Share														Common Stock Dividends Declared, $2.25 Per Share	—		—		—		(1,319)		—		(1,319)
Other Comprehensive Income	Other Comprehensive Income	—		—		2		—		—		2		Other Comprehensive Income	—		—		6		—		—		6
Common Stock Issued Under Stock Plans	Common Stock Issued Under Stock Plans	—		—		—		—		—		—		Common Stock Issued Under Stock Plans	—		—		—		—		—		—
Change in Treasury Stock - Stock Compensation Plans, Net	Change in Treasury Stock - Stock Compensation Plans, Net	—		(5)		—		—		(17)		(22)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(5)		—		—		(33)		(38)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(5)		—		—		5		—		Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		51		—		—		—		51		Stock-Based Compensation Expenses	—		34		—		—		—		34
Treasury Stock Issued as Compensation		—		—		—		—		—		—
Balance at September 30, 2021		$	206	$	6,058	$	(13)	$	15,542	$	(28)	$	21,765
Balance at September 30, 2022														Balance at September 30, 2022	$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849

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

-5-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Millions, Except Per Share Data)

(Unaudited)


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity			Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at December 31, 2021		$	206	$	6,087	$	(12)	$	15,919	$	(20)	$	22,180
Balance at December 31, 2022														Balance at December 31, 2022	$	206	$	6,187	$	(8)	$	18,472	$	(78)	$	24,779
Net Income	Net Income	—		—		—		5,482		—		5,482		Net Income	—		—		—		5,606		—		5,606
Common Stock Dividends Declared, $6.55 Per Share		—		—		—		(3,838)		—		(3,838)
Common Stock Dividends Declared, $3.475 Per Share														Common Stock Dividends Declared, $3.475 Per Share	—		—		—		(2,031)		—		(2,031)
Other Comprehensive Income	Other Comprehensive Income	—		—		6		—		—		6		Other Comprehensive Income	—		—		1		—		—		1
Common Stock Issued Under Stock Plans	Common Stock Issued Under Stock Plans	—		13		—		—		—		13		Common Stock Issued Under Stock Plans	—		—		—		—		—		—
Change in Treasury Stock - Stock Compensation Plans, Net		—		(40)		—		—		(53)		(93)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(4)		—		—		4		—		Restricted Stock and Restricted Stock Units, Net	—		(156)		—		—		156		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		99		—		—		—		99		Stock-Based Compensation Expenses	—		126		—		—		—		126
Treasury Stock Issued as Compensation		—		—		—		—		—		—
Balance at September 30, 2022		$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849
Treasury Stock Repurchased														Treasury Stock Repurchased	—		—		—		—		(676)		(676)
Change in Treasury Stock - Stock Compensation Plans, Net														Change in Treasury Stock - Stock Compensation Plans, Net	—		(24)		—		—		(23)		(47)
Balance at September 30, 2023														Balance at September 30, 2023	$	206	$	6,133	$	(7)	$	22,047	$	(621)	$	27,758


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity			Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at December 31, 2020		$	206	$	5,945	$	(12)	$	14,170	$	(7)	$	20,302
Balance at December 31, 2021														Balance at December 31, 2021	$	206	$	6,087	$	(12)	$	15,919	$	(20)	$	22,180
Net Income	Net Income	—		—		—		2,679		—		2,679		Net Income	—		—		—		5,482		—		5,482
Common Stock Dividends Declared, $2.2375 Per Share		—		—		—		(1,307)		—		(1,307)
Other Comprehensive Loss		—		—		(1)		—		—		(1)
Common Stock Dividends Declared, $6.55 Per Share														Common Stock Dividends Declared, $6.55 Per Share	—		—		—		(3,838)		—		(3,838)
Other Comprehensive Income														Other Comprehensive Income	—		—		6		—		—		6
Common Stock Issued Under Stock Plans	Common Stock Issued Under Stock Plans	—		9		—		—		—		9		Common Stock Issued Under Stock Plans	—		13		—		—		—		13
Change in Treasury Stock - Stock Compensation Plans, Net	Change in Treasury Stock - Stock Compensation Plans, Net	—		(7)		—		—		(27)		(34)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(40)		—		—		(53)		(93)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(6)		—		—		6		—		Restricted Stock and Restricted Stock Units, Net	—		(4)		—		—		4		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		117		—		—		—		117		Stock-Based Compensation Expenses	—		99		—		—		—		99
Treasury Stock Issued as Compensation	Treasury Stock Issued as Compensation	—		—		—		—		—		—		Treasury Stock Issued as Compensation	—		—		—		—		—		—
Balance at September 30, 2021		$	206	$	6,058	$	(13)	$	15,542	$	(28)	$	21,765
Balance at September 30, 2022														Balance at September 30, 2022	$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849

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

-6-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Millions)

(Unaudited)


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Cash Flows from Operating Activities	Cash Flows from Operating Activities					Cash Flows from Operating Activities
Reconciliation of Net Income to Net Cash Provided by Operating Activities:	Reconciliation of Net Income to Net Cash Provided by Operating Activities:					Reconciliation of Net Income to Net Cash Provided by Operating Activities:
Net Income	Net Income	$	5,482	$	2,679	Net Income	$	5,606	$	5,482
Items Not Requiring (Providing) Cash	Items Not Requiring (Providing) Cash					Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	2,664		2,741		Depreciation, Depletion and Amortization	2,562		2,664
Impairments	Impairments	240		170		Impairments	123		240
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	99		117		Stock-Based Compensation Expenses	126		99
Deferred Income Taxes	Deferred Income Taxes	(240)		(244)		Deferred Income Taxes	484		(240)
Gains on Asset Dispositions, Net	Gains on Asset Dispositions, Net	(101)		(46)		Gains on Asset Dispositions, Net	(95)		(101)
Other, Net	Other, Net	(15)		15		Other, Net	5		(15)
Dry Hole Costs	Dry Hole Costs	41		28		Dry Hole Costs	1		41
Mark-to-Market Financial Commodity Derivative Contracts	Mark-to-Market Financial Commodity Derivative Contracts					Mark-to-Market Financial Commodity Derivative Contracts
Total Losses		4,215		1,288
(Gains) Losses, Net						(Gains) Losses, Net	(520)		4,215
Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(3,257)		(516)		Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(130)		(3,257)
Other, Net	Other, Net	33		8		Other, Net	(2)		33
Changes in Components of Working Capital and Other Assets and Liabilities	Changes in Components of Working Capital and Other Assets and Liabilities					Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	Accounts Receivable	(1,008)		(639)		Accounts Receivable	(239)		(1,008)
Inventories	Inventories	(311)		95		Inventories	(331)		(311)
Accounts Payable	Accounts Payable	301		115		Accounts Payable	(70)		301
Accrued Taxes Payable	Accrued Taxes Payable	24		286		Accrued Taxes Payable	200		24
Other Assets	Other Assets	(271)		(55)		Other Assets	3		(271)
Other Liabilities	Other Liabilities	(548)		(317)		Other Liabilities	200		(548)
Changes in Components of Working Capital Associated with Investing Activities	Changes in Components of Working Capital Associated with Investing Activities	301		(100)		Changes in Components of Working Capital Associated with Investing Activities	313		301
Net Cash Provided by Operating Activities	Net Cash Provided by Operating Activities	7,649		5,625		Net Cash Provided by Operating Activities	8,236		7,649
Investing Cash Flows	Investing Cash Flows					Investing Cash Flows
Additions to Oil and Gas Properties	Additions to Oil and Gas Properties	(3,390)		(2,689)		Additions to Oil and Gas Properties	(4,025)		(3,390)
Additions to Other Property, Plant and Equipment	Additions to Other Property, Plant and Equipment	(248)		(147)		Additions to Other Property, Plant and Equipment	(638)		(248)
Proceeds from Sales of Assets	Proceeds from Sales of Assets	310		154		Proceeds from Sales of Assets	135		310
Other Investing Activities	Other Investing Activities	(30)		—		Other Investing Activities	—		(30)
Changes in Components of Working Capital Associated with Investing Activities	Changes in Components of Working Capital Associated with Investing Activities	(301)		100		Changes in Components of Working Capital Associated with Investing Activities	(313)		(301)
Net Cash Used in Investing Activities	Net Cash Used in Investing Activities	(3,659)		(2,582)		Net Cash Used in Investing Activities	(4,841)		(3,659)
Financing Cash Flows	Financing Cash Flows					Financing Cash Flows
Long-Term Debt Repayments	Long-Term Debt Repayments	—		(750)		Long-Term Debt Repayments	(1,250)		—
Dividends Paid	Dividends Paid	(3,821)		(1,278)		Dividends Paid	(2,041)		(3,821)
Treasury Stock Purchased	Treasury Stock Purchased	(95)		(33)		Treasury Stock Purchased	(728)		(95)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	17		9		Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	10		17
Debt Issuance Costs						Debt Issuance Costs	(8)		—
Repayment of Finance Lease Liabilities	Repayment of Finance Lease Liabilities	(27)		(27)		Repayment of Finance Lease Liabilities	(24)		(27)
Net Cash Used in Financing Activities	Net Cash Used in Financing Activities	(3,926)		(2,079)		Net Cash Used in Financing Activities	(4,041)		(3,926)
Effect of Exchange Rate Changes on Cash	Effect of Exchange Rate Changes on Cash	(1)		—		Effect of Exchange Rate Changes on Cash	—		(1)
Increase in Cash and Cash Equivalents		63		964
Increase (Decrease) in Cash and Cash Equivalents						Increase (Decrease) in Cash and Cash Equivalents	(646)		63
Cash and Cash Equivalents at Beginning of Period	Cash and Cash Equivalents at Beginning of Period	5,209		3,329		Cash and Cash Equivalents at Beginning of Period	5,972		5,209
Cash and Cash Equivalents at End of Period	Cash and Cash Equivalents at End of Period	$	5,272	$	4,293	Cash and Cash Equivalents at End of Period	$	5,326	$	5,272

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

-7-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Summary of Significant Accounting Policies

General. The condensed consolidated financial statements of EOG Resources, Inc., together with its subsidiaries (collectively, EOG), included herein have been prepared by management without audit pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Accordingly, they reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the financial results for the interim periods presented. Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) have been condensed or omitted pursuant to such rules and regulations. However, management believes that the disclosures included either on the face of the financial statements or in these notes are sufficient to make the interim information presented not misleading. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in EOG's Annual Report on Form 10-K for the year ended December 31, ~~2021,~~2022, filed on February ~~24,~~23, 2023 (EOG's 2022 ~~(EOG's 2021~~ Annual Report).

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three and nine months ended September 30, ~~2022,~~2023, are not necessarily indicative of the results to be expected for the full year.

~~Recently Issued Accounting Standards.~~ In March 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2020-04, "Reference Rate Reform (Topic 848)" (ASU 2020-04), which provides optional expedients and exceptions for accounting treatment of contracts which are affected by the anticipated discontinuation of the London InterBank Offered Rate (LIBOR) and other rates resulting from rate reform. Contract terms that are modified due to the replacement of a reference rate are not required to be remeasured or reassessed under relevant accounting standards. Early adoption is permitted. ASU 2020-04 covers certain contracts which reference these rates and that are entered into on or before December 31, 2022. EOG has evaluated the provisions of ASU 2020-04 and has concluded that the application of ASU 2020-04 will not have a material impact on its consolidated financial statements and related disclosures related to its $2.0 billion senior unsecured Revolving Credit Agreement.

~~-8-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

2. Stock-Based Compensation

As more fully discussed in Note 7 to the Consolidated Financial Statements included in EOG's ~~2021~~2022 Annual Report, EOG maintains various stock-based compensation plans. Stock-based compensation expense is included on the Condensed Consolidated Statements of Income and Comprehensive Income based upon the job function of the employees receiving the grants as follows (in millions):

Three Months Ended
September 30, Nine Months Ended
September 30,
2022 2021 2022 2021
Lease and Well $ 6 $ 11 $ 29 $ 36
Gathering and Processing Costs 1 1 3 2
Exploration Costs — 4 10 15
General and Administrative 27 35 57 64
Total $ 34 $ 51 $ 99 $ 117

The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provided for grants of stock options, stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, performance units and other stock-based awards.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Lease and Well	$	16	$	6	$	39	$	29
Gathering and Processing Costs	1		1		3		3
Exploration Costs	8		—		18		10
General and Administrative	32		27		66		57
Total	$	57	$	34	$	126	$	99

EOG's stockholders approved the EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (2021 Plan) at the 2021 Annual Meeting of Stockholders. Therefore, no further grants were made from the Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) from and after the April 29, 2021 effective date of the 2021 Plan. The 2021 Plan provides for grants of stock options, ~~SARs,~~stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, restricted stock units with performance-based conditions (together with the performance units granted under the 2008 Plan, Performance Units) and other stock-based awards, up to an aggregate maximum of 20 million shares of common stock, plus any shares that ~~are~~were subject to outstanding awards under the 2008 Plan as of April 29, 2021, that are subsequently canceled, forfeited, expire or are otherwise not issued or are settled in cash. Under the 2021 Plan, grants may be made to employees and non-employee members of EOG's Board of Directors (Board).

At September 30, ~~2022,~~2023, approximately 1615 million common shares remained available for grant under the 2021 Plan. EOG's policy is to issue shares related to the 2021 Plan grants from previously authorized unissued shares or treasury shares to the extent treasury shares are available.

-8-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Stock Options and Stock-Settled Stock Appreciation Rights and Employee Stock Purchase Plan. The fair value of stock option grants and SAR grants is estimated using the Hull-White II binomial option pricing model. The fair value of Employee Stock Purchase Plan (ESPP) grants is estimated using the Black-Scholes-Merton model. Stock-based compensation expense related to stock option, SAR and ESPP grants totaled ~~$11~~$8 million and ~~$20~~$11 million during the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and ~~$28~~$20 million and ~~$39~~$28 million during the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

EOG did not grant any stock options or SARs during the nine-month period ended September 30, 2023. Weighted average fair values and valuation assumptions used to value stock ~~option, SAR~~options and SARs granted during the nine-month period ended September 30, 2022 and ESPP grants during the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 are as follows:


		Stock Options/SARs						ESPP							Stock Options/SARs			ESPP
		Nine Months Ended September 30,						Nine Months Ended September 30,							Nine Months Ended September 30,			Nine Months Ended September 30,
		2022			2021			2022			2021				2022			2023			2022
Weighted Average Fair Value of Grants	Weighted Average Fair Value of Grants	$	28.30		$	24.92		$	26.71		$	18.15		Weighted Average Fair Value of Grants	$	28.30		$	29.39		$	26.71
Expected Volatility	Expected Volatility	42.20		%	42.24		%	43.08		%	51.23		%	Expected Volatility	42.20		%	38.07		%	43.08		%
Risk-Free Interest Rate	Risk-Free Interest Rate	0.89		%	0.50		%	1.33		%	0.07		%	Risk-Free Interest Rate	0.89		%	5.02		%	1.33		%
Dividend Yield	Dividend Yield	3.28		%	2.25		%	2.88		%	2.88		%	Dividend Yield	3.28		%	2.67		%	2.88		%
Expected Life	Expected Life	5.3 years			5.2 years			0.5 years			0.5 years			Expected Life	5.3 years			0.5 years			0.5 years

~~-9-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

Expected volatility is based on an equal weighting of historical volatility and implied volatility from traded options in EOG's common stock. The risk-free interest rate is based upon United States Treasury yields in effect at the time of grant. The expected life is based upon historical experience and contractual terms of stock option, SAR and ESPP grants.

The following table sets forth stock option and SAR transactions for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (stock options and SARs in thousands):


		Nine Months Ended September 30, 2022			Nine Months Ended September 30, 2021				Nine Months Ended September 30, 2023			Nine Months Ended September 30, 2022
		Number of Stock Options/SARs	Weighted Average Exercise Price		Number of Stock Options/SARs	Weighted Average Exercise Price			Number of Stock Options/SARs	Weighted Average Exercise Price		Number of Stock Options/SARs	Weighted Average Exercise Price
Outstanding at January 1	Outstanding at January 1	9,969	$	84.37	10,186	$	84.08	Outstanding at January 1	4,225	$	77.49	9,969	$	84.37
Granted	Granted	2	97.64		1,976	81.66		Granted	—	—		2	97.64
Exercised (1)	Exercised (1)	(4,282)	91.63		(448)	64.18		Exercised (1)	(924)	76.88		(4,282)	91.63
Forfeited	Forfeited	(192)	84.26		(984)	98.64		Forfeited	(78)	86.69		(192)	84.26
Outstanding at September 30 (2)	Outstanding at September 30 (2)	5,497	$	78.73	10,730	$	83.13	Outstanding at September 30 (2)	3,223	$	77.45	5,497	$	78.73
Vested or Expected to Vest (3)	Vested or Expected to Vest (3)	5,344	$	79.05	10,407	$	83.65	Vested or Expected to Vest (3)	3,175	$	77.38	5,344	$	79.05
Exercisable at September 30 (4)	Exercisable at September 30 (4)	3,686	$	84.18	6,906	$	92.39	Exercisable at September 30 (4)	2,646	$	76.53	3,686	$	84.18

(1)The total intrinsic value of stock options/SARs exercised during the nine months ended September 30, 2023 and 2022 ~~and 2021~~ was ~~$122~~$46 million and $8$122 million, respectively. The intrinsic value is based upon the difference between the market price of EOG's common stock on the date of exercise and the exercise price of the stock options/SARs.

(2)The total intrinsic value of stock options/SARs outstanding at September 30, 2023 and 2022 ~~and 2021~~ was ~~$194~~$159 million and ~~$95~~$194 million, respectively. At ~~both~~ September 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was 3.6 years and 4.3 ~~years.~~years, respectively.

(3)The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2023 and 2022 ~~and 2021~~ was ~~$187~~$157 million and ~~$90~~$187 million, respectively. At ~~both~~ September 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was 3.6 years and 4.3 ~~years.~~years, respectively.

(4)The total intrinsic value of stock options/SARs exercisable at September 30, 2023 and 2022 ~~and 2021~~ was ~~$114~~$133 million and ~~$38~~$114 million, respectively. At September 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was ~~3.7~~3.3 years and ~~3.2~~3.7 years, respectively.

-9-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

At September 30, ~~2022,~~2023, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled ~~$38~~$17 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.7~~0.9 years.

Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Stock-based compensation expense related to restricted stock and restricted stock units totaled ~~$18~~$43 million and ~~$20~~$18 million for the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and ~~$63~~$95 million and ~~$65~~$63 million for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

~~-10-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

The following table sets forth restricted stock and restricted stock unit transactions for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (shares and units in thousands):


		Nine Months Ended September 30, 2022			Nine Months Ended September 30, 2021				Nine Months Ended September 30, 2023			Nine Months Ended September 30, 2022
		Number of Shares and Units	Weighted Average Grant Date Fair Value		Number of Shares and Units	Weighted Average Grant Date Fair Value			Number of Shares and Units	Weighted Average Grant Date Fair Value		Number of Shares and Units	Weighted Average Grant Date Fair Value
Outstanding at January 1	Outstanding at January 1	4,680	$	69.37	4,742	$	74.97	Outstanding at January 1	4,113	$	80.77	4,680	$	69.37
Granted	Granted	1,623	113.03		1,409	81.44		Granted	1,629	131.33		1,623	113.03
Released (1)	Released (1)	(1,953)	82.05		(1,321)	101.63		Released (1)	(1,208)	40.27		(1,953)	82.05
Forfeited	Forfeited	(130)	65.44		(65)	68.49		Forfeited	(85)	84.25		(130)	65.44
Outstanding at September 30 (2)	Outstanding at September 30 (2)	4,220	$	80.41	4,765	$	69.58	Outstanding at September 30 (2)	4,449	$	110.21	4,220	$	80.41

(1)The total intrinsic value of restricted stock and restricted stock units released during the nine months ended September 30, 2023 and 2022, ~~and 2021~~ was ~~$215~~$156 million and ~~$104~~$215 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the restricted stock and restricted stock units are released.

(2)The total intrinsic value of restricted stock and restricted stock units outstanding at September 30, 2023 and 2022, ~~and 2021~~ was ~~$472~~$564 million and ~~$383~~$472 million, respectively.

At September 30, ~~2022,~~2023, unrecognized compensation expense related to restricted stock and restricted stock units totaled ~~$313~~$398 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 2.0 years.

Performance Units. EOG grants Performance Units annually to its executive officers without cost to them. For the grants made prior to September 2022, as more fully discussed in the grant agreements, the applicable performance metric is EOG's total shareholder return (TSR) over a three-year performance period relative to the TSR over the same period of a designated group of peer companies. Upon the application of the applicable performance multiple at the completion of the three-year performance period, a minimum of 0% and a maximum of 200% of the Performance Units granted could be outstanding.

For the grants made beginning in September 2022, as more fully discussed in the grant agreements, the applicable performance metrics are 1) EOG's TSR over a three-year performance period relative to the TSR over the same period of a designated group of peer companies and 2) EOG's average return on capital employed (ROCE) over the three-year performance period. At the end of the three-year performance period, a performance multiple based on ~~EOGs~~EOG's relative TSR ranking will be determined, with a minimum performance multiple of 0% and a maximum performance multiple of 200%. A specified modifier ranging from -70% to +70% will then be applied to the performance multiple based on EOG's average ROCE over the three-year performance period, provided that in no event shall the performance multiple, after applying the ROCE modifier, be less than 0% or exceed 200%. Furthermore, if EOG's TSR over the three-year performance period is negative (i.e., less than 0%), the performance multiple will be capped at 100%, regardless of EOG's relative TSR ranking or three-year average ROCE.

The fair value of the Performance Units is estimated using a Monte Carlo simulation. Stock-based compensation expense related to the Performance Unit grants totaled $5$6 million and ~~$11~~$5 million for the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and $8$11 million and ~~$13~~$8 million for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

~~-11-~~-10-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The following table sets forth the Performance Unit transactions for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (units in thousands):

Nine Months Ended
September 30, 2022 Nine Months Ended
September 30, 2021
Number of
Units Weighted
Average
Grant Date Fair Value Number of
Units Weighted
Average
Grant Date Fair Value
Outstanding at January 1 679 $ 84.97 613 $ 88.38
Granted 122 126.55 222 90.94
Granted for Performance Multiple (1)
— — 19 113.81
Released (2)
(57) 136.74 (175) 113.06
Forfeited for Performance Multiple (3)
(56) 136.74 — —
Outstanding at September 30 (4)
688 (5) $ 83.82 679 $ 83.59


	Nine Months Ended September 30, 2023				Nine Months Ended September 30, 2022
	Number of Units		Weighted Average Grant Date Fair Value		Number of Units	Weighted Average Grant Date Fair Value
Outstanding at January 1	688		$	83.82	679	$	84.97
Granted	109		141.59		122	126.55
Released (1)	(86)		79.98		(57)	136.74
Forfeited for Performance Multiple (2)	(86)		79.98		(56)	136.74
Outstanding at September 30 (3)	625	(4)	$	94.94	688	$	83.82

(1)Upon completion of the Performance Period for the Performance Units granted in 2017, a performance multiple of 125% was applied to the grants resulting in an additional grant of Performance Units in February 2021.

~~(2)~~The total intrinsic value of Performance Units released was $7$10 million and ~~$13~~$7 million for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Units are released.

~~(3)~~(2)Upon completion of the Performance Period for the Performance Units granted in 2019 and 2018, a performance multiple of 50% was applied to each of the grants resulting in a forfeiture of Performance Units in both February 2023 and February 2022.

~~(4)~~(3)The total intrinsic value of Performance Units outstanding at September 30, ~~2022~~2023 and ~~2021~~2022, was approximately ~~$77~~$79 million and ~~$55~~$77 million, respectively.

~~(5)~~(4)Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of zero and a maximum of ~~1,376~~1,249 Performance Units could be outstanding.

At September 30, ~~2022,~~2023, unrecognized compensation expense related to Performance Units totaled ~~$20~~$22 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.8~~1.9 years.

3. Net Income Per Share

The following table sets forth the computation of Net Income Per Share for the three-month and nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions, except per share data):


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Numerator for Basic and Diluted Earnings Per Share -	Numerator for Basic and Diluted Earnings Per Share -									Numerator for Basic and Diluted Earnings Per Share -
Net Income	Net Income	$	2,854	$	1,095	$	5,482	$	2,679	Net Income	$	2,030	$	2,854	$	5,606	$	5,482
Denominator for Basic Earnings Per Share -	Denominator for Basic Earnings Per Share -									Denominator for Basic Earnings Per Share -
Weighted Average Shares	Weighted Average Shares	583		581		583		580		Weighted Average Shares	579		583		581		583
Potential Dilutive Common Shares -	Potential Dilutive Common Shares -									Potential Dilutive Common Shares -
Stock Options/SARs/ESPP	Stock Options/SARs/ESPP	1		1		2		1		Stock Options/SARs/ESPP	1		1		1		2
Restricted Stock/Units and Performance Units	Restricted Stock/Units and Performance Units	3		2		2		3		Restricted Stock/Units and Performance Units	3		3		2		2
Denominator for Diluted Earnings Per Share -	Denominator for Diluted Earnings Per Share -									Denominator for Diluted Earnings Per Share -
Adjusted Diluted Weighted Average Shares	Adjusted Diluted Weighted Average Shares	587		584		587		584		Adjusted Diluted Weighted Average Shares	583		587		584		587
Net Income Per Share	Net Income Per Share									Net Income Per Share
Basic	Basic	$	4.90	$	1.88	$	9.40	$	4.62	Basic	$	3.51	$	4.90	$	9.65	$	9.40
Diluted	Diluted	$	4.86	$	1.88	$	9.34	$	4.59	Diluted	$	3.48	$	4.86	$	9.60	$	9.34

~~-12-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

The diluted earnings per share calculation excludes stock option, SAR and ESPP grants that were anti-dilutive. Shares underlying the excluded stock option, SAR and ESPP grants were ~~1 million~~zero and 71 million for the three-month periods ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and were 1 million ~~and 7 million shares~~ for both the nine-month periods ended September 30, ~~2022~~2023 and ~~2021, respectively.~~2022.

-11-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

4. Supplemental Cash Flow Information

Net cash paid for interest and income taxes was as follows for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Interest (1)	Interest (1)	$	123	$	134	Interest (1)	$	110	$	123
Income Taxes, Net of Refunds Received	Income Taxes, Net of Refunds Received	$	2,059	$	775	Income Taxes, Net of Refunds Received	$	876	$	2,059

(1)Net of capitalized interest of ~~$26~~$24 million and ~~$24~~$26 million for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

EOG's accrued capital expenditures and amounts recorded within accounts payable at September 30, 2023 and 2022 ~~and 2021~~ were ~~$575~~$716 million and ~~$405~~$575 million, respectively.

Non-cash investing activities for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, included additions of ~~$113~~$154 million and ~~$41~~$113 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the nine months ended September 30, 2021, also included additions of $74 million to EOG's other property, plant and equipment made in connection with finance lease transactions for storage facilities.

Operating activities for the nine months ended September 30, 2023 and 2022, included net cash received of $324 million and ~~2021, included the~~ net ~~use of~~ cash used of $546 million, ~~and $308 million,~~ respectively, related to the change in collateral posted for financial commodity derivative contracts. For related discussion, see Note 12. ~~This amount is~~These amounts are reflected in Other Liabilities within the Changes in Components of Working Capital and Other Assets and Liabilities line item on the Condensed Consolidated Statements of Cash Flows.

~~-13-~~-12-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

5. Segment Information

Selected financial information by reportable segment is presented below for the three-month and nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Operating Revenues and Other	Operating Revenues and Other									Operating Revenues and Other
United States	United States	$	7,481	$	4,692	$	18,733	$	12,293	United States	$	6,164	$	7,481	$	17,625	$	18,733
Trinidad	Trinidad	111		72		249		229		Trinidad	48		111		203		249
Other International (1)	Other International (1)	1		1		1		76		Other International (1)	—		1		1		1
Total	Total	$	7,593	$	4,765	$	18,983	$	12,598	Total	$	6,212	$	7,593	$	17,829	$	18,983
Operating Income (Loss)	Operating Income (Loss)									Operating Income (Loss)
United States	United States	$	3,606	$	1,455	$	7,010	$	3,422	United States	$	2,559	$	3,606	$	7,032	$	7,010
Trinidad	Trinidad	73		37		132		121		Trinidad	17		73		99		132
Other International (1) (2)	Other International (1) (2)	(15)		(21)		(29)		31		Other International (1) (2)	(19)		(15)		(32)		(29)
Total	Total	3,664		1,471		7,113		3,574		Total	2,557		3,664		7,099		7,113
Reconciling Items	Reconciling Items									Reconciling Items
Other Income, Net	Other Income, Net	40		6		66		—		Other Income, Net	52		40		168		66
Interest Expense, Net	Interest Expense, Net	(41)		(48)		(137)		(140)		Interest Expense, Net	(36)		(41)		(113)		(137)
Income Before Income Taxes	Income Before Income Taxes	$	3,663	$	1,429	$	7,042	$	3,434	Income Before Income Taxes	$	2,573	$	3,663	$	7,154	$	7,042

(1) Other International primarily consists of EOG's ~~China~~international exploration programs and Canada operations. ~~The China operations were sold in the second quarter of 2021.~~ EOG began exploration programs in Australia in the third quarter of 2021 and in Oman in the third quarter of 2020. The decision was reached in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman.

(2) EOG recorded pretax impairment charges of ~~$10~~$14 million and ~~$13~~$10 million for the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and ~~$12~~$18 million and ~~$15~~$12 million for the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.

Total assets by reportable segment are presented below at September 30, ~~2022~~2023 and December 31, ~~2021~~2022 (in millions):


		At September 30, 2022		At December 31, 2021			At September 30, 2023		At December 31, 2022
Total Assets	Total Assets					Total Assets
United States	United States	$	39,521	$	37,436	United States	$	42,532	$	40,349
Trinidad	Trinidad	831		637		Trinidad	989		879
Other International (1)	Other International (1)	135		163		Other International (1)	126		143
Total	Total	$	40,487	$	38,236	Total	$	43,647	$	41,371

~~-14-~~-13-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

6. Asset Retirement Obligations

The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of short-term and long-term legal obligations associated with the retirement of property, plant and equipment for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Carrying Amount at January 1	Carrying Amount at January 1	$	1,231	$	1,217	Carrying Amount at January 1	$	1,328	$	1,231
Liabilities Incurred	Liabilities Incurred	83		55		Liabilities Incurred	49		83
Liabilities Settled (1)	Liabilities Settled (1)	(178)		(83)		Liabilities Settled (1)	(80)		(178)
Accretion	Accretion	32		33		Accretion	37		32
Revisions	Revisions	102		(7)		Revisions	166		102
Foreign Currency Translation	Foreign Currency Translation	(5)		—		Foreign Currency Translation	—		(5)
Carrying Amount at September 30	Carrying Amount at September 30	$	1,265	$	1,215	Carrying Amount at September 30	$	1,500	$	1,265

Current Portion	Current Portion	$	38	$	54	Current Portion	$	42	$	38
Noncurrent Portion	Noncurrent Portion	$	1,227	$	1,161	Noncurrent Portion	$	1,458	$	1,227

(1)Includes settlements related to asset sales.

The current and noncurrent portions of EOG's asset retirement obligations are included in Current Liabilities - Other and Other Liabilities, respectively, on the Condensed Consolidated Balance Sheets.

7. Exploratory Well Costs

EOG's net changes in capitalized exploratory well costs for the nine-month period ended September 30, ~~2022,~~2023, are presented below (in millions):


	Nine Months Ended September 30, ~~2022~~2023
Balance at January 1	$	715
Additions Pending the Determination of Proved Reserves	93133
Reclassifications to Proved Properties	~~(12)~~(35)
Costs Charged to Expense~~(1)~~	~~(35)~~(1)
Balance at September 30	$	53112


	Nine Months Ended September 30, 2023
Capitalized exploratory well costs that have been capitalized for a period of one year or less	$	109
Capitalized exploratory well costs that have been capitalized for a period greater than one year (1)	3
Balance at September 30	$	112

Number of exploratory wells that have been capitalized for a period greater than one year	2

(1)~~Includes capitalized exploratory well~~Consists of costs ~~charged~~related to ~~either dry hole costs or impairments.~~projects in the United States at September 30, 2023.

~~At September 30, 2022, all capitalized exploratory well costs had been capitalized for periods of less than one year.~~

-14-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

8. Commitments and Contingencies

There are currently various suits and claims pending against EOG that have arisen in the ordinary course of EOG's business, including contract disputes, personal injury and property damage claims and title disputes. While the ultimate outcome and impact on EOG cannot be predicted, management believes that the resolution of these suits and claims will not, individually or in the aggregate, have a material adverse effect on EOG's consolidated financial position, results of operations or cash flow. EOG records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

~~-15-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

9. Pension and Postretirement Benefits

Pension Plans. EOG has a defined contribution pension plan in place for most of its employees in the United States. EOG's contributions to the pension plan are based on various percentages of compensation and, in some instances, are based upon the amount of the employees' contributions. EOG's total costs recognized for the pension plan were ~~$37~~$42 million and ~~$36~~$37 million for the nine months ended September 30, 2023 and 2022, ~~and 2021.~~respectively. In addition, EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan, both of which are available to most of the employees of the Trinidadian subsidiary, the costs of which are not material.

Postretirement Health Care. EOG has postretirement medical and dental benefits in place for eligible United States and Trinidad employees and their eligible dependents, the costs of which are not material.

10. Long-Term Debt and Common Stock

Long-Term Debt. EOG had no outstanding commercial paper borrowings at September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, and did not utilize any commercial paper borrowings during the nine months ended September 30, ~~2022~~2023 and ~~2021.~~2022.

~~At September 30, 2022,~~On March 15, 2023, EOG repaid upon maturity the $1,250 million aggregate principal amount of ~~EOG's~~its 2.625% Senior Notes due ~~2023 were classified as Current Portion of Long-Term Debt on the Condensed Consolidated Balance Sheets.~~2023.

On June 7, 2023, EOG ~~currently has~~entered into a $1.9 billion senior unsecured Revolving Credit Agreement (New Facility) with domestic and foreign lenders (Banks).The New Facility replaced EOG's $2.0 billion senior unsecured Revolving Credit Agreement, ~~(Agreement)~~dated as of June 27, 2019, with domestic and foreign lenders ~~(Banks).~~ (2019 Facility), which had a scheduled maturity date of June 27, 2024 and was terminated by EOG (without penalty), effective as of June 7, 2023, in connection with the completion of the New Facility.

The ~~Agreement~~New Facility has a scheduled maturity date of June ~~27, 2024,~~7, 2028 and includes an option for EOG to extend, on up to two occasions, the term for successive one-year periods, subject to, among certain other terms and ~~conditions.~~conditions, the consent of the Banks holding greater than 50% of the commitments then outstanding under the New Facility. The ~~Agreement (i)~~New Facility commits the Banks to provide advances up to an aggregate principal amount of ~~$2.0~~$1.9 billion outstanding at any ~~one~~given time, ~~outstanding,~~ with an option for EOG to request increases in the aggregate commitments to an amount not to exceed $3.0 billion, subject to certain terms and ~~conditions and (ii)~~conditions. The New Facility also includes a swingline subfacility and a letter of credit subfacility. Advances under the ~~Agreement~~New Facility will accrue interest based, at EOG's option, on either ~~LIBOR~~the Secured Overnight Financing Rate (SOFR) plus 0.1% plus an applicable margin, ~~(Eurodollar rate)~~ or the ~~base rate~~Base Rate (as defined in the ~~Agreement)~~New Facility) plus an applicable margin. The ~~Agreement~~applicable margin used in connection with interest rates and fees will be based on EOG's credit rating for its senior unsecured long-term debt at the applicable time.

Consistent with the terms of the 2019 Facility, the New Facility contains representations, warranties, covenants and events of default that EOG believes are customary for ~~investment-grade,~~investment grade, senior unsecured commercial bank credit agreements, including a financial covenant for the maintenance of a ratio of ~~total debt-to-capitalization~~Total Debt to Total Capitalization (as such terms are defined in the ~~Agreement)~~New Facility) of no greater than 65%. At September 30, ~~2022,~~2023, EOG was in compliance with this financial covenant. At

There were no borrowings or letters of credit outstanding under the 2019 Facility as of (i) December 31, 2022 or (ii) the June 7, 2023 effective date of the closing of the New Facility and termination of the 2019 Facility. Further, at September 30, ~~2022 and December 31, 2021,~~2023, there were no borrowings or letters of credit outstanding under the ~~Agreement.~~New Facility. The ~~Eurodollar rate~~SOFR and ~~base rate~~Base Rate (inclusive of the applicable ~~margin)~~margins), had there been any amounts borrowed under the ~~Agreement~~New Facility at September 30, ~~2022,~~2023, would have been ~~4.04%~~6.32% and ~~6.25%~~8.50%, respectively.

-15-

EOG RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Common Stock. In November 2021, the Board established a new share repurchase authorization that allows for the repurchase by EOG of up to $5 billion of its common stock (November 2021 Authorization).Under the November 2021 Authorization, EOG may repurchase shares from time to time, at management's discretion, in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. The timing and amount of repurchases is at the discretion of EOG's management and depends on a variety of factors, including the trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares are held as treasury shares and are available for general corporate purposes. The November 2021 Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board at any time. During the three and nine months ended September 30, 2023, EOG repurchased 0.5 million and 6.2 million shares of common stock, respectively, for approximately $60.9 million and $671.1 million (inclusive of transaction fees and commissions), respectively, pursuant to the November 2021 Authorization. As of September 30, 2023, approximately $4.3 billion remained available for repurchases under the November 2021 Authorization. Included in the Treasury Stock Repurchased amounts on the Condensed Consolidated Statements of Stockholders' Equity for the nine months ended September 30, 2023, is $5.2 million of estimated federal excise taxes.

On February ~~24, 2022,~~23, 2023, the Board declared a quarterly cash dividend on the common stock of ~~$0.75~~$0.825 per share, paid on April ~~29, 2022,~~28, 2023, to stockholders of record as of April ~~15, 2022.~~14, 2023. The Board also declared on such date a special cash dividend on the common stock of $1.00 per share, paid on March ~~29, 2022,~~30, 2023, to stockholders of record as of March ~~15, 2022.~~16, 2023.

On May ~~5, 2022,~~4, 2023, the Board declared a quarterly cash dividend on the common stock of ~~$0.75~~$0.825 per share paid on July ~~29, 2022,~~31, 2023, to stockholders of record as of July ~~15, 2022.The Board also declared on such date a special dividend of $1.80 per share paid on June 30, 2022, to stockholders of record as of June 15, 2022.~~17, 2023.

On August ~~4, 2022, the Board declared a special dividend on the common stock of $1.50 per share paid on September 29, 2022, to stockholders of record as of September 15, 2022.~~

~~On September 29, 2022,~~3, 2023, the Board declared a quarterly cash dividend on the common stock of ~~$0.75~~$0.825 per share ~~payable~~paid on October 31, ~~2022,~~2023, to stockholders of record as of October 17, ~~2022. At September 30, 2022, this quarterly cash dividend was accrued as Dividends Payable on the Condensed Consolidated Balance Sheets.~~2023.

On November ~~3, 2022,~~2, 2023, the Board (i) increased the quarterly cash dividend on the common stock from the previous ~~$0.75~~$0.825 per share to ~~$0.825~~$0.91 per share, effective beginning with the dividend payable on January 31, ~~2023,~~2024, to stockholders of record as of January 17, ~~2023,~~2024, and (ii) declared a special cash dividend on the common stock of $1.50 per share, payable on December ~~30, 2022,~~29, 2023, to stockholders of record as of December 15, ~~2022.~~2023.

-16-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

11. Fair Value Measurements

Recurring Fair Value Measurements. As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's ~~2021~~2022 Annual Report, certain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Condensed Consolidated Balance Sheets. The following table provides fair value measurement information within the fair value hierarchy for certain of EOG's financial assets and liabilities carried at fair value on a recurring basis at September 30, ~~2022~~2023 and December 31, ~~2021~~2022 (in millions):


		Fair Value Measurements Using:									Fair Value Measurements Using:
		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total			Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
At September 30, 2022
At September 30, 2023										At September 30, 2023
Financial Assets:	Financial Assets:									Financial Assets:
Natural Gas Basis Swaps	Natural Gas Basis Swaps	$	—	$	29	$	—	$	29	Natural Gas Basis Swaps	$	—	$	5	$	—	$	5
Financial Liabilities:	Financial Liabilities:									Financial Liabilities:
Crude Oil Swaps		—		297		—		297
Natural Gas Swaps	Natural Gas Swaps	—		1,052		—		1,052		Natural Gas Swaps	—		282		—		282
Crude Oil Roll Differential Swaps		—		8		—		8

At December 31, 2021
At December 31, 2022										At December 31, 2022
Financial Assets:	Financial Assets:									Financial Assets:
Natural Gas Swaps		$	—	$	29	$	—	$	29
Natural Gas Basis Swaps	Natural Gas Basis Swaps	—		2		—		2		Natural Gas Basis Swaps	$	—	$	29	$	—	$	29
Crude Oil Swaps		—		15		—		15
Financial Liabilities:	Financial Liabilities:									Financial Liabilities:
Crude Oil Roll Differential Swaps		—		24		—		24
Natural Gas Swaps	Natural Gas Swaps	—		121		—		121		Natural Gas Swaps	—		703		—		703
Crude Oil Swaps	Crude Oil Swaps	—		340		—		340		Crude Oil Swaps	—		190		—		190
Natural Gas Basis Swaps		—		1		—		1

See Note 12 for the balance sheet amounts and classification of EOG's financial commodity derivative instruments at September 30, ~~2022~~2023 and December 31, ~~2021.~~2022.

The estimated fair value of financial commodity derivative contracts was based upon forward commodity price curves based on quoted market prices. Financial commodity derivative contracts were valued by utilizing an independent third-party derivative valuation provider who uses various types of valuation models, as applicable.

Non-Recurring Fair Value Measurements. The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and is based on internal estimates of future retirement costs associated with property, plant and equipment. Significant Level 3 inputs used in the calculation of asset retirement obligations include plugging costs and reserve lives. A reconciliation of EOG's asset retirement obligations is presented in Note 6.

~~-17-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

When circumstances indicate that proved oil and gas properties may be impaired, EOG compares expected undiscounted future cash flows at a depreciation, depletion and amortization group level to the unamortized capitalized cost of the asset. If the expected undiscounted future cash flows, based on EOG's estimate of (and assumptions regarding) significant Level 3 inputs, including future crude oil, natural gas liquids (NGLs) and natural gas prices, operating costs, development expenditures, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated using the Income Approach described in the FASB's Fair Value Measurement Topic of the Accounting Standards Codification. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.

EOG utilized average prices per acre from comparable market transactions and estimated discounted cash flows as the basis for determining the fair value of unproved and proved properties, respectively, received in non-cash property exchanges. See Note 4.

-17-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Fair Value Disclosures. EOG's financial instruments, other than financial commodity derivative contracts, consist of cash and cash equivalents, accounts receivable, accounts payable and current and long-term debt. The carrying values of cash and cash equivalents, accounts receivable and accounts payable approximate fair value.

At ~~both~~ September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively, EOG had outstanding $3,640 million and $4,890 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately ~~$4,667~~$3,373 million and ~~$5,577~~$4,740 million, respectively. The estimated fair value of debt was based upon quoted market prices and, where such prices were not available, other observable (Level 2) inputs regarding interest rates available to EOG at the end of each respective period.

~~-18-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

12. Risk Management Activities

Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's ~~2021~~2022 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method.

Financial Commodity Derivative Contracts. Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the nine-month period ended September 30, ~~2022~~2023 (closed) and outstanding as of September 30, ~~2022.~~2023. Crude oil volumes are presented in thousand barrels per day (MBbld) and prices are presented in dollars per barrel ($/Bbl). Natural gas volumes are presented in million British Thermal Units per day (MMBtud) and prices are presented in dollars per million British Thermal Units ($/MMBtu).

Crude Oil Financial Price Swap Contracts
Contracts Sold Contracts Purchased
Period Settlement Index Volume
(MBbld) Weighted Average Price
($/Bbl) Volume (MBbld) Weighted Average Price
($/Bbl)
January - March 2022 (closed) New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI) 140 $ 65.58 — $ —
April - June 2022 (closed) NYMEX WTI 140 65.62 — —
July - September 2022 (closed) NYMEX WTI 140 65.59 — —
October - December 2022 (closed) (1)
NYMEX WTI 53 66.11 — —
October - December 2022 NYMEX WTI 87 65.41 87 88.85
January - March 2023 (closed) (1) (2)
NYMEX WTI 55 67.96 — —
January - March 2023 NYMEX WTI 95 67.90 6 102.26
April - May 2023 (closed) (1)
NYMEX WTI 29 68.28 — —
April - May 2023 NYMEX WTI 91 67.63 2 98.15
June 2023 (closed) (1)
NYMEX WTI 118 67.77 — —
June 2023 NYMEX WTI 2 69.10 2 98.15
July - September 2023 (closed) (1)
NYMEX WTI 100 70.15 — —
October - December 2023 (closed) (1)
NYMEX WTI 69 69.41 — —


Crude Oil Financial Price Swap Contracts
		Contracts Sold			Contracts Purchased
Period	Settlement Index	Volume (MBbld)	Weighted Average Price ($/Bbl)		Volume (MBbld)	Weighted Average Price ($/Bbl)

January - March 2023 (closed)	New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI)	95	$	67.90	6	$	102.26
April - May 2023 (closed)	NYMEX WTI	91	67.63		2	98.15
June 2023 (closed)	NYMEX WTI	2	69.10		2	98.15

(1) In the second quarter of 2022, EOG executed the early termination provision granting EOG the right to terminate certain of its October 2022 - December 2023 crude oil financial price swap contracts which were open at that time. EOG paid net cash of $593 million for the settlement of these contracts.

(2) In the third quarter of 2022, EOG executed the early termination provision granting EOG the right to terminate certain of its January 2023 - March 2023 crude oil financial price swap contracts which were open at that time. EOG paid net cash of $63 million for the settlement of these contracts.

Natural Gas Financial Price Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price
($/MMBtu)

January - October 2023 (closed)

NYMEX Henry Hub

300

3.36

November - December 2023

NYMEX Henry Hub

300

3.36

January - December 2024

NYMEX Henry Hub

725

3.07

January - December 2025

NYMEX Henry Hub

725

3.07

~~-19-~~-18-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Crude Oil Basis Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MBbld) Weighted Average Price Differential
($/Bbl)
January - October 2022 (closed)
NYMEX WTI Roll Differential (1)
125 $ 0.15
November - December 2022
NYMEX WTI Roll Differential (1)
125 0.15

~~(1) This settlement index is used to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month.~~

Natural Gas Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price
($/MMBtu)
January - September 2022 (closed) NYMEX Henry Hub 725 $ 3.57
October - December 2022 (closed) (1)
NYMEX Henry Hub 425 3.05
October (closed) NYMEX Henry Hub 300 4.32
November - December 2022 NYMEX Henry Hub 300 4.32
January - December 2023 (closed) (1)
NYMEX Henry Hub 425 3.05
January - December 2023 NYMEX Henry Hub 300 3.36
January - December 2024 NYMEX Henry Hub 725 3.07
January - December 2025 NYMEX Henry Hub 725 3.07

(1) In the second quarter of 2022, EOG executed the early termination provision granting EOG the right to terminate certain of its October 2022 - December 2023 natural gas financial price swap contracts which were open at that time. EOG paid net cash of $735 million for the settlement of these contracts.

Natural Gas Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price Differential
($/MMBtu)

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price Differential
($/MMBtu)

January - September 2022 (closed)

NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)

210

0.01

October - December 2022

NYMEX Henry Hub HSC Differential (1)

210

0.01

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

0.01

January - September 2023 (closed)

NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)

135

0.01

October - December 2023

NYMEX Henry Hub HSC Differential

135

0.01

January - December 2024

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2024

NYMEX Henry Hub HSC Differential

0.00

January - December 2025

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2025

NYMEX Henry Hub HSC Differential

0.00

(1) This settlement index is used to fix the differential between pricing at the Houston Ship Channel and NYMEX Henry Hub prices.

~~-20-~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)~~

~~(Unaudited)~~

Financial Commodity ~~Derivatives~~Derivative Instruments Location on Balance Sheet. The following table sets forth the amounts and classification of EOG's outstanding financial commodity derivative instruments at September 30, ~~2022~~2023 and December 31, ~~2021.~~2022. Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions):

Fair Value at

Description

Location on Balance Sheet

September 30, 2022

December 31, 2021

Description

Location on Balance Sheet

September 30, 2023

December 31, 2022

Asset Derivatives

Crude oil and natural gas derivative contracts -

Noncurrent Portion

Other Assets (1)

—

Liability Derivatives

Crude oil and natural gas derivative contracts -

Crude oil, NGLs and natural gas derivative contracts -

Current portion

Liabilities from Price Risk Management Activities (2)

243

269

Current portion

Liabilities from Price Risk Management Activities (1)

169

Noncurrent portion

Other Liabilities (3)

399

Noncurrent portion

Other Liabilities (2)

255

371

(1) ~~The noncurrent portion of Assets from Price Risk Management Activities consists of gross assets of $7 million, partially offset by gross liabilities of $1 million at December 31, 2021.~~

~~(2)~~ The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$547~~$26 million, partially offset by gross assets of ~~$25~~$4 million and no collateral posted, ~~with counterparties of $279 million~~ at September 30, ~~2022.~~2023. The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$421~~$287 million, partially offset by gross assets of ~~$29~~$26 million and collateral posted with counterparties of ~~$123~~$92 million, at December 31, ~~2021.~~2022.

~~(3)~~(2) The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$810~~$256 million, partially offset by gross assets of $4$1 million and no collateral posted ~~with counterparties of $407 million~~ at September 30, ~~2022.~~2023. The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$64~~$606 million, partially offset by gross assets of ~~$10~~$3 million and collateral posted with counterparties of ~~$17~~$232 million, at December 31, ~~2021.~~2022.

-19-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)

(Unaudited)

Credit Risk. Notional contract amounts are used to express the magnitude of a financial derivative. The amounts potentially subject to credit risk, in the event of nonperformance by the counterparties, are equal to the fair value of such contracts (see Note 11). EOG evaluates its exposures to significant counterparties on an ongoing basis, including those arising from physical and financial transactions. In some instances, EOG renegotiates payment terms and/or requires collateral, parent guarantees or letters of credit to minimize credit risk.

All of EOG's derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that require EOG, if it is the party in a net liability position, to post collateral when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings. In addition, the ISDAs may also provide that as a result of certain circumstances, including certain events that cause EOG's credit ratings to become materially weaker than its then-current ratings, the counterparty may require all outstanding derivatives under the ISDAs to be settled immediately. See Note 11 for the aggregate fair value of all derivative instruments that were in a net liability position at both September 30, ~~2022~~2023 and December 31, ~~2021.~~2022. EOG had ~~$686 million of~~no collateral posted and no collateral held at September 30, ~~2022.~~2023. EOG had ~~$140~~$324 million of collateral posted and no collateral held at December 31, ~~2021. Due to changes in contracted volumes and commodity prices subsequent to September 30, 2022,~~2022. EOG had ~~$623 million of~~no collateral posted and no collateral held at November ~~2, 2022.~~1, 2023.

~~-21-~~

13. Acquisitions and Divestitures

During the nine months ended September 30, 2023, EOG paid cash of $134 million, primarily to acquire a gathering and processing system in the Powder River Basin. Additionally, during the nine months ended September 30, 2023, EOG recognized net gains on asset dispositions of $95 million and received proceeds of $135 million, primarily due to the sale of EOG's equity interest in ammonia plant investments in Trinidad, the sale of certain legacy assets in the Texas Panhandle, the sale of certain gathering and processing assets and the sale of certain other assets.

During the nine months ended September 30, 2022, EOG paid cash for property acquisitions of $392 million in the United States. Additionally, during the nine months ended September 30, 2022, EOG recognized net gains on asset dispositions of $101 million and received proceeds of approximately $310 million, primarily due to the sale of certain legacy natural gas assets in the Rocky Mountain area, unproved leasehold in Texas and producing properties in the Mid-Continent area.

During the nine months ended September 30, 2021, EOG paid cash for property acquisitions of $95 million in the United States. Additionally, during the nine months ended September 30, 2021, EOG recognized net gains on asset dispositions of $46 million and received proceeds of approximately $154 million, primarily due to the sale of its China operations during the second quarter of 2021.

-20-

~~-22-~~

PART I. FINANCIAL INFORMATION

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EOG RESOURCES, INC.

Overview

EOG Resources, Inc., together with its subsidiaries (collectively, EOG), is one of the largest independent (non-integrated) crude oil and natural gas companies in the United States with proved reserves in the United States and ~~Trinidad.~~the Republic of Trinidad and Tobago (Trinidad). EOG operates under a consistent business and operational strategy that focuses predominantly on maximizing the rate of return on investment of capital by controlling operating and capital costs and maximizing reserve recoveries. Pursuant to this strategy, each prospective drilling location is evaluated by its estimated rate of return. This strategy is intended to enhance the generation of cash flow and earnings from each unit of production on a cost-effective basis, allowing EOG to ~~deliver~~maximize long-term ~~growth in~~ shareholder value and maintain a strong balance sheet. EOG implements its strategy primarily by emphasizing the drilling of internally generated prospects in order to find and develop low-cost reserves. Maintaining the lowest possible operating cost structure, coupled with efficient and safe operations and robust environmental stewardship practices and performance, is integral in the implementation of EOG's strategy.

Commodity Prices. Prices for crude oil and condensate, natural gas liquids (NGLs) and natural gas have historically been volatile. This volatility is expected to continue due to the many uncertainties associated with the world political and economic environment and the global supply of, and demand for, crude oil, NGLs and natural gas and the availability of other energy supplies, the relative competitive relationships of the various energy sources in the view of consumers and other factors.

The market prices of crude oil and condensate, NGLs and natural gas impact the amount of cash generated from EOG's operating activities, which, in turn, impact EOG's financial position and results of operations.

For the first nine months of ~~2022,~~2023, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were ~~$98.14~~$77.37 per barrel and ~~$6.77~~$2.69 per million British thermal units (MMBtu), respectively, representing ~~increases~~decreases of ~~51%~~21% and ~~113%~~60%, respectively, from the average NYMEX prices for the same period in ~~2021.~~2022. Market prices for NGLs are influenced by the components extracted, including ethane, propane and butane and natural gasoline, among others, and the respective market pricing for each component.

The increases in crude oil and natural gas prices during the first nine months of 2022 were due to numerous factors, including the continued recovery in demand for crude oil, natural gas and NGLs from the impacts of the COVID-19 pandemic; low worldwide inventory levels; continued supply restraint by OPEC+ (a consortium of OPEC (Organization of Petroleum Exporting Countries) and certain non-OPEC global producers); and the impact resulting from the ongoing conflict between Russia and Ukraine.

Inflation Considerations; Availability of Materials, Labor & Services.Beginning in the second half of 2021 and continuing, to a lesser degree, through the first ~~nine~~three months of ~~2022,~~2023, EOG, similar to other companies in its industry, ~~has~~ experienced inflationary pressures on its operating and capital costs - namely the costs of fuel, steel (i.e., wellbore tubulars and facilities manufactured using steel), labor and drilling and completion services. Such inflationary pressures ~~have~~ resulted from (i) supply chain disruptions caused by the COVID-19 pandemic and the resulting limited availability of certain materials and products manufactured using such materials; (ii) increased demand for fuel and steel; (iii) increased demand for drilling and completion services coupled with a limited number of available service providers, resulting in increased competition for such services among EOG and other companies in its industry; (iv) labor shortages; and (v) other factors, including the ongoing conflict between Russia and the Ukraine which began in late February 2022. Beginning in the second quarter of 2023, EOG ~~currently expects such~~has seen these inflationary pressures diminish and, ~~contributing factors~~in certain circumstances, seen a decline in prices. However, the market for such materials, services and labor continues to ~~continue into 2023.~~fluctuate and, as a result, the timing and impact of any price changes on EOG's future operating and capital costs is uncertain.

~~-23-~~

Such inflationary pressures on EOG's operating and capital costs have, in turn, impacted its cash flows and results of operations. However, by virtue of its continued focus on increasing its drilling, completion and operating efficiencies and improving the performance of its wells, as well as the flexibility provided by its multi-basin drilling portfolio, EOG has, to date, been able to largely offset such impacts. EOG currently expects such inflationary pressures to result in an increase of ~~less~~no more than 10 percent in its fiscal year ~~2022~~2023 well costs (i.e., its costs for drilling, completions and well-site facilities) versus fiscal year ~~2021.~~2022. Accordingly, such increase in EOG's fiscal year ~~2022~~2023 well costs ~~has~~did not ~~to date, had~~have a material impact on EOG's ~~results of operations,~~third quarter 2023 cash flows, and EOG currently does not expect such increase to have a material impact on its full-year ~~2022 results of operations.~~2023 cash flows. Further, such inflationary pressures and the factors contributing to such inflationary pressures (described above) have not, to date, impacted EOG's results of operations, liquidity, capital resources, cash requirements or financial position or its ability to conduct its day-to-day drilling, completion and production operations.

-21-

The initiatives EOG has undertaken (and continues to undertake) to increase its drilling, completion and operating efficiencies and improve the performance of its wells and, in turn, mitigate such inflationary pressures, include (among others): (i) EOG's downhole drilling motor program, which has resulted in increased footage drilled per day and, in turn, reduced drilling times; (ii) enhanced techniques for completing its wells, which has resulted in increased footage completed per day and pumping hours per day; and (iii) EOG's self-sourced sand program, which has resulted in continued ~~costs~~cost savings for the sand utilized in its well completion operations. In addition, EOG enters into agreements with its service providers from time to time, when available and advantageous, to secure the costs and availability of certain ~~of the~~ drilling and completion services it utilizes as part of its operations.

EOG plans to continue with these initiatives and actions, though there can be no assurance that such efforts will offset, largely or at all, the impacts of any future inflationary pressures on EOG's operating and capital costs, cash flows and results of operations. Further, there can be no assurance that the factors contributing to any future inflationary pressures will not impact EOG's ability to conduct its future day-to-day drilling, completion and production operations.

Climate Change. For discussion of climate change matters and related regulatory matters, including potential developments related to climate change and the potential impacts and risks of such developments on EOG, see ITEM 1A. Risk Factors and the related discussion in ITEM 1. Business - Regulation of EOG's Annual Report on Form 10-K for the year ended December 31, 2022, filed on February 23, 2023 (EOG's 2022 Annual Report). EOG will continue to monitor and assess any climate change-related developments that could impact EOG and the oil and gas industry, to determine the impact on its business and operations, and take appropriate actions where necessary.

United States. EOG's efforts to identify plays with large reserve potential have proven to be successful. EOG continues to drill numerous wells in large acreage plays, which in the aggregate have contributed substantially to, and are expected to continue to contribute substantially to, EOG's crude oil and condensate, NGLs and natural gas production. EOG has placed an emphasis on applying its horizontal drilling and completion expertise to unconventional crude oil plays and natural gas plays.

During the first nine months of ~~2022,~~2023, EOG continued to focus on increasing drilling, completion and operating efficiencies, to improve well performance and, as is further discussed above, to mitigate inflationary pressures on its operating and capital costs (e.g., costs for fuel and tubulars). In addition, EOG continued to evaluate certain potential crude oil and condensate, NGLs and natural gas exploration and development prospects and to look for opportunities to add drilling inventory through leasehold acquisitions, farm-ins, exchanges or tactical or bolt-on acquisitions. On a volumetric basis, as calculated using ~~the~~a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas, crude oil and condensate and NGLs production accounted for approximately 73% and 75% of EOG's United States production during ~~both~~ the first nine months of ~~2022~~2023 and ~~2021,~~2022, respectively. During the first nine months of ~~2022,~~2023, EOG's drilling and completion activities occurred primarily in the Delaware Basin play, Eagle Ford ~~oil~~ play and Rocky Mountain area. EOG's major producing areas in the United States are in New Mexico and Texas.

Trinidad. In ~~the Republic of~~ Trinidad, ~~and Tobago (Trinidad),~~ EOG continues to deliver natural gas under existing supply contracts. Several fields in the South East Coast Consortium Block, Modified U(a) Block, Block 4(a), ~~Modified U(b) Block,~~ the Banyan Field and the Sercan Area have been developed and are producing natural gas which is sold to the National Gas Company of Trinidad and Tobago Limited and its subsidiary (NGC), and crude oil and condensate which is sold to Heritage Petroleum Company Limited (Heritage). In July 2022, EOG amended the natural gas sales contract with NGC to extend the term and provide for an increase in price realizations if index prices for certain commodities exceed specified levels. The pricing component of this amendment was effective September 2020.

~~In March 2021,~~ EOG signed a farmout agreement with Heritage, which allows EOG to earn a 65% working interest in a portion of the contract area (EOG Area) governed by the Trinidad Northern Area License. The EOG Area is located offshore the southwest coast of Trinidad. In the first nine months of 2022, EOG prepared for and drilled one net exploratory well, which was determined to be unsuccessful.

~~-24-~~

~~Also,~~commenced drilling in the ~~first nine months~~third quarter of ~~2022, EOG continued to make progress on~~2023 from the ~~design, fabrication and installation of the~~recently completed platform ~~and related facilities for its previously-announced discovery~~ in the Modified U(a) Block. InFrom this platform, EOG expects to complete two net developmental wells and one net exploratory well in the fourth quarter of ~~2022, EOG expects to complete the installation of the platform~~2023 and, ~~facilities and commence the development drilling campaign~~ in the ~~Modified U(a) Block.~~first quarter of 2024, complete one net development well and one net exploratory well. Additionally, in the first nine months of ~~2022,~~2023, EOG ~~commenced~~completed the ~~drilling of one net exploratory well from a pre-existing~~design phase for the platform and related facilities in the ~~Modified U(a) Block, which was in progress at September 30, 2022. In the fourth quarter~~Mento Area and commenced construction of ~~2022, EOG also expects to complete~~such platform and ~~put on production one net exploratory well that was started~~related facilities in the third quarter of ~~2022 and to drill one additional net exploratory well from~~2023.

Also, EOG sold its equity interest in its ammonia plant investments in the ~~same platform.~~first quarter of 2023.

Other International. In November 2021, a subsidiary of EOG was granted an exploration permit for the WA-488-P Block, located offshore Western Australia. In the first nine months of ~~2022,~~2023, EOG continued to prepare for the drilling of an exploration well which is expected to commence in ~~2023,~~2024, subject to statutory ~~approvals.~~approvals and equipment availability.

EOG continues to evaluate other select crude oil and natural gas opportunities outside the United States, primarily by pursuing exploitation opportunities in countries where indigenous crude oil and natural gas reserves have been identified.

-22-

~~2022~~

2023 Capital and Operating Plan. Total ~~2022~~2023 capital expenditures are estimated to range from approximately ~~$4.5~~$5.9 billion to ~~$4.7~~$6.1 billion, including facilities and gathering, processing, transportation and other expenditures, and excluding acquisitions, non-cash transactions and exploration costs. EOG plans to continue to focus a substantial portion of its exploration and development expenditures in its major producing areas in the United States. In particular, EOG will be focused on United States drilling activity in the Delaware Basin, Eagle Ford ~~oil~~ play, Rocky Mountain area and Dorado gas play where it generates its highest ~~rates-of-return.~~rates of return. To further enhance the economics of these plays, EOG expects to continue to improve well performance and to mitigate ~~recent~~ inflationary pressures on its operating and capital costs (e.g., costs for fuel and tubulars) through drilling, completion and operating efficiency gains; see the above related discussion. Full-year ~~2022~~2023 total crude oil, NGLs and natural gas production is expected to ~~return to pre-pandemic levels.~~increase modestly versus 2022. In addition, EOG plans to continue to spend a portion of its anticipated ~~2022~~2023 capital expenditures on leasing acreage, evaluating new prospects, transportation infrastructure and environmental projects.

Management continues to believe EOG has one of the strongest prospect inventories in EOG's history. When it fits EOG's strategy, EOG will make acquisitions that bolster existing drilling programs or offer incremental exploration and/or production opportunities.

Capital Structure. One of management's key strategies is to maintain a strong balance sheet with a consistently below average debt-to-total capitalization ratio as compared to those in EOG's peer group. EOG's debt-to-total capitalization ratio was ~~18%~~12% and ~~19%~~17% at September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, respectively. As used in this calculation, total capitalization represents the sum of total current and long-term debt and total stockholders' equity.

At September 30, ~~2022,~~2023, EOG maintained a strong financial and liquidity position, including $5.3 billion of cash and cash equivalents on hand and ~~$2.0~~$1.9 billion of availability under its senior unsecured revolving credit ~~facility.~~facility (discussed below).

On June 7, 2023, EOG entered into a $1.9 billion senior unsecured Revolving Credit Agreement (New Facility) with domestic and foreign lenders. The New Facility replaced EOG's $2.0 billion senior unsecured Revolving Credit Agreement, dated as of June 27, 2019, with domestic and foreign lenders, which had a scheduled maturity date of June 27, 2024 and was terminated by EOG (without penalty), effective as of June 7, 2023, in connection with the completion of the New Facility.

On March 15, 2023, EOG repaid upon maturity the $1,250 million aggregate principal amount of its 2.625% Senior Notes due 2023.

EOG has significant flexibility with respect to financing alternatives, including borrowings under its commercial paper program, bank borrowings, borrowings under its senior unsecured revolving credit facility, joint development agreements and similar agreements and equity and debt offerings.

~~Dividend Declarations.~~ On February 24, 2022, EOG's Board of Directors (Board) declared a quarterly cash dividend on the common stock of $0.75 per share paid on April 29, 2022, to stockholders of record as of April 15, 2022. The Board also declared on such date a special dividend of $1.00 per share paid on March 29, 2022, to stockholders of record as of March 15, 2022.

On May 5, 2022, the Board declared a quarterly cash dividend on the common stock of $0.75 per share paid on July 29, 2022, to stockholders of record as of July 15, 2022. The Board also declared on such date a special dividend of $1.80 per share paid on June 30, 2022, to stockholders of record as of June 15, 2022.

~~On August 4, 2022, the Board declared a special dividend on the common stock of $1.50 per share paid on September 29, 2022, to stockholders of record as of September 15, 2022.~~

~~On September 29, 2022, the Board declared a quarterly cash dividend on the common stock of $0.75 per share paid on October 31, 2022, to stockholders of record as of October 17, 2022.~~

~~-25-~~

On November 3, 2022, the Board (i) increased the quarterly cash dividend on the common stock from the previous $0.75 per share to $0.825 per share, effective beginning with the dividend payable on January 31, 2023, to stockholders of record as of January 17, 2023, and (ii) declared a special cash dividend on the common stock of $1.50 per share, payable on December 30, 2022, to stockholders of record as of December 15, 2022.

Cash Return Framework. ~~Also on~~In May 5, 2022, EOG announced the addition of quantitative guidance to its cash return framework - specifically, a commitment to return a minimum of 60% of annual net cash provided by operating activities before certain balance sheet-related changes, less total capital expenditures, to stockholders, through a combination of quarterly dividends, special dividends and share repurchases.On November 2, 2023, EOG announced an increase in such cash return commitment – specifically, a commitment, effective beginning with fiscal year 2024, to return a minimum of 70% of annual net cash provided by operating activities before certain balance sheet-related changes, less total capital expenditures, to stockholders, through a combination of quarterly dividends, special dividends and share repurchases.

For ~~related~~ discussion regarding our payment of dividends, see ITEM 1A. Risk Factorsand ITEM 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securitiesof EOG's 2022 Annual Report. For discussion regarding our share repurchases conducted during the third quarter of 2023 and our share repurchase authorization, see Part II, Item 2.Unregistered Sales of Equity Securities and Use of Proceedsin this Quarterly Report on Form ~~10-K for the year ended December 31, 2021, filed on February 24, 2022 (EOG's 2021 Annual Report).~~10-Q.

Dividend Declarations. On February 23, 2023, EOG's Board of Directors (Board) declared a quarterly cash dividend on the common stock of $0.825 per share, paid on April 28, 2023, to stockholders of record as of April 14, 2023. The Board also declared on such date a special dividend on the common stock of $1.00 per share, paid on March 30, 2023, to stockholders of record as of March 16, 2023.

On May 4, 2023, the Board declared a quarterly cash dividend on the common stock of $0.825 per share paid on July 31, 2023, to stockholders of record as of July 17, 2023.

-23-

On August 3, 2023, the Board declared a quarterly cash dividend on the common stock of $0.825 per share paid on October 31, 2023, to stockholders of record as of October 17, 2023.

On November 2, 2023, the Board (i) increased the quarterly cash dividend on the common stock from the previous $0.825 per share to $0.91 per share, effective beginning with the dividend payable on January 31, 2024, to stockholders of record as of January 17, 2024, and (ii) declared a special cash dividend on the common stock of $1.50 per share, payable on December 29, 2023, to stockholders of record as of December 15, 2023.

Share Repurchases. In November 2021, the Board established a new share repurchase authorization that allows for the repurchase by EOG of up to $5 billion of its common stock (November 2021 Authorization). Under the November 2021 Authorization, EOG may repurchase shares from time to time, at management's discretion, in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. The timing and amount of repurchases is at the discretion of EOG's management and depends on a variety of factors, including the trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares are held as treasury shares and are available for general corporate purposes. The November 2021 Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board at any time. During the three and nine months ended September 30, 2023, EOG repurchased 0.5 million and 6.2 million shares of common stock, respectively, for approximately $60.9 million and $671.1 million (inclusive of transaction fees and commissions), respectively, pursuant to the November 2021 Authorization. As of September 30, 2023, approximately $4.3 billion remained available for repurchases under the November 2021 Authorization. Included in the Treasury Stock Repurchased amounts on the Condensed Consolidated Statements of Stockholders' Equity for the nine months ended September 30, 2023, is $5.2 million of estimated federal excise taxes.

-24-

Results of Operations

The following review of operations for the three months ended September 30, ~~2022~~2023 and ~~2021~~2022 should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form ~~10-Q.~~10‑Q.

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

Operating ~~Revenues and Other.~~Revenues. During the third quarter of ~~2022,~~2023, operating revenues ~~increased $2,828~~decreased $1,381 million, or ~~59%~~18%, to ~~$7,593~~$6,212 million from ~~$4,765~~$7,593 million for the same period of ~~2021.~~2022. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the third quarter of ~~2022 increased $1,992~~2023 decreased $1,402 million, or ~~49%~~23%, to ~~$6,037~~$4,635 million from ~~$4,045~~$6,037 million for the same period of ~~2021.~~2022. EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$18~~$43 million for the third quarter of ~~2022~~2023 compared to net losses of ~~$494~~$18 million for the same period of ~~2021.~~2022. Gathering, processing and marketing revenues for the third quarter of ~~2022 increased $375~~2023 decreased $83 million, or ~~32%~~5%, to ~~$1,561~~$1,478 million from ~~$1,186~~$1,561 million for the same period of ~~2021.~~2022. Net ~~losses~~gains on asset dispositions were ~~$21~~$35 million for the third quarter of ~~2022~~2023 compared to net ~~gains~~losses of $1$21 million for the same period of ~~2021.~~2022.

~~-26-~~-25-

Wellhead volume and price statistics for the three-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 were as follows:


		Three Months Ended September 30,						Three Months Ended September 30,
		2022			2021			2023		2022
Crude Oil and Condensate Volumes (MBbld) (1)	Crude Oil and Condensate Volumes (MBbld) (1)						Crude Oil and Condensate Volumes (MBbld) (1)
United States	United States	464.6			448.3		United States	482.8		464.6
Trinidad	Trinidad	0.5			1.2		Trinidad	0.5		0.5
Other International (2)		—			—
Total	Total	465.1			449.5		Total	483.3		465.1
Average Crude Oil and Condensate Prices ($/Bbl) (3)
Average Crude Oil and Condensate Prices ($/Bbl) (2)							Average Crude Oil and Condensate Prices ($/Bbl) (2)
United States	United States	$	96.05		$	70.88	United States	$	83.61	$	96.05
Trinidad	Trinidad	84.98			60.19		Trinidad	71.38		84.98
Other International (2)		—			—
Composite	Composite	96.04			70.85		Composite	83.60		96.04
Natural Gas Liquids Volumes (MBbld) (1)	Natural Gas Liquids Volumes (MBbld) (1)						Natural Gas Liquids Volumes (MBbld) (1)
United States	United States	209.3			157.9		United States	231.1		209.3
Total	Total	209.3			157.9		Total	231.1		209.3
Average Natural Gas Liquids Prices ($/Bbl) (3)
Average Natural Gas Liquids Prices ($/Bbl) (2)							Average Natural Gas Liquids Prices ($/Bbl) (2)
United States	United States	$	36.02		$	37.72	United States	$	23.56	$	36.02
Composite		36.02			37.72
Natural Gas Volumes (MMcfd) (1)	Natural Gas Volumes (MMcfd) (1)						Natural Gas Volumes (MMcfd) (1)
United States	United States	1,306			1,210		United States	1,562		1,306
Trinidad	Trinidad	163			212		Trinidad	142		163
Other International (2)		—			—
Total	Total	1,469			1,422		Total	1,704		1,469
Average Natural Gas Prices ($/Mcf) (3)
Average Natural Gas Prices ($/Mcf) (2)							Average Natural Gas Prices ($/Mcf) (2)
United States	United States	$	9.35		$	4.50	United States	$	2.59	$	9.35
Trinidad	Trinidad	7.45		(5)	3.39		Trinidad	3.41		7.45		(4)
Other International (2)		—			—
Composite	Composite	9.14			4.34		Composite	2.66		9.14
Crude Oil Equivalent Volumes (MBoed) (4)
Crude Oil Equivalent Volumes (MBoed) (3)							Crude Oil Equivalent Volumes (MBoed) (3)
United States	United States	891.6			807.9		United States	974.2		891.6
Trinidad	Trinidad	27.6			36.5		Trinidad	24.3		27.6
Other International (2)		—			—
Total	Total	919.2			844.4		Total	998.5		919.2

Total MMBoe (4)		84.6			77.7
Total MMBoe (3)							Total MMBoe (3)	91.9		84.6

(1)Thousand barrels per day or million cubic feet per day, as applicable.

(2)~~Other International includes EOG's China and Canada operations. The China operations were sold in the second quarter of 2021.~~

~~(3)~~Dollars per barrel or per thousand cubic feet, as applicable. Excludes the impact of financial commodity derivative instruments (see Note 12 to the Condensed Consolidated Financial Statements).

~~(4)~~(3)Thousand barrels of oil equivalent per day or million barrels of oil equivalent, as applicable; includes crude oil and condensate, NGLs and natural gas. Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas. MMBoe is calculated by multiplying the MBoed amount by the number of days in the period and then dividing that amount by one thousand.

~~(5)~~(4)Includes revenue adjustment of $3.37 per Mcf ($0.37 per Mcf of EOG's composite wellhead natural gas price) related to a price adjustment per a provision of the natural gas sales contract with NGC amended in July 2022 for natural gas sales during the period from September 2020 through June 2022.

~~-27-~~-26-

Wellhead crude oil and condensate revenues for the third quarter of ~~2022 increased $1,180~~2023 decreased $392 million, or ~~40%~~10%, to ~~$4,109~~$3,717 million from ~~$2,929~~$4,109 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite average price ($~~1,087~~556 million) ~~and~~, partially offset by an increase of ~~15.6~~18.2 MBbld, or 3%4%, in wellhead crude oil and condensate production ($93164 million). Increased production was primarily in the Permian ~~Basin, partially offset by decreased production in the Eagle Ford oil play and the Rocky Mountain area.~~Basin. EOG's composite wellhead crude oil and condensate price for the third quarter of ~~2022 increased 36%~~2023 decreased 13% to ~~$96.04~~$83.60 per barrel compared to ~~$70.85~~$96.04 per barrel for the same period of ~~2021.~~2022.

NGL revenues for the third quarter of ~~2022 increased $145~~2023 decreased $192 million, or ~~26%~~28%, to ~~$693~~$501 million from ~~$548~~$693 million for the same period of ~~2021~~2022 due to ~~an increase of 51.4 MBbld, or 33%, in NGL deliveries ($177 million), partially offset by~~ a lower composite average price ($32264 million), partially offset by an increase of 21.8 MBbld, or 10%, in NGL deliveries ($72 million). Increased production was primarily from the Permian Basin. EOG's composite NGL price for the third quarter of ~~2022~~2023 decreased 5%35% to ~~$36.02~~$23.56 per barrel compared to ~~$37.72~~$36.02 per barrel for the same period of ~~2021.~~2022.

Wellhead natural gas revenues for the third quarter of ~~2022 increased $667~~2023 decreased $818 million, or ~~117%~~66%, to ~~$1,235~~$417 million from ~~$568~~$1,235 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite average ~~composite~~ price ($~~650~~1,019 million) ~~and~~, partially offset by an increase in natural gas deliveries ($17201 million). Natural gas deliveries for the third quarter of ~~2022~~2023 increased 47235 MMcfd, or 3%16%, compared to the same period of ~~2021~~2022 due primarily to ~~higher deliveries in the Dorado gas play and~~ increased production of associated natural gas from the Permian Basin and higher deliveries in the Dorado gas play and the Rocky Mountain area, partially offset by lower natural gas deliveries in ~~Trinidad and lower natural gas volumes due to the sale of certain legacy natural gas assets in the Rocky Mountain area in the first quarter of 2022.~~Trinidad. EOG's composite wellhead natural gas price for the third quarter of ~~2022 increased 111%~~2023 decreased 71% to ~~$9.14~~$2.66 per Mcf compared to ~~$4.34~~$9.14 per Mcf for the same period of ~~2021.~~2022.

During the third quarter of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$18~~$43 million compared to net losses of ~~$494~~$18 million for the same period of ~~2021.~~2022. During the third quarter of ~~2022,~~2023, net cash received from settlements of financial commodity derivative contracts was $23 million compared to net cash paid for settlements of financial commodity derivative contracts ~~was~~of $847 million, of which $63 million was related to the early termination of certain contracts scheduled to settle after December 31, 2022. Net cash paid for settlements of financial commodity derivative contracts was $293 million for the same period of ~~2021.~~2022.

Gathering, processing and marketing revenues are revenues generated from sales of third-party crude oil, NGLs and natural gas, as well as fees associated with gathering third-party natural gas and revenues from sales of EOG-owned sand. Purchases and sales of third-party crude oil and natural gas may be utilized in order to balance firm capacity at third-party facilities with production in certain areas and to utilize excess capacity at EOG-owned facilities. EOG sells sand primarily in order to balance the timing of firm purchase agreements with completion operations. Marketing costs represent the costs to purchase third-party crude oil, natural gas and sand and the associated transportation costs, as well as costs associated with EOG-owned sand sold to third parties.

Gathering, processing and marketing revenues less marketing costs for the third quarter of ~~2022 decreased $62~~2023 increased $155 million as compared to the same period of ~~2021~~2022 primarily due to ~~lower~~higher margins on crude oil marketing activities, partially offset by ~~higher~~lower margins on natural gas marketing activities.

~~-28-~~-27-

Operating and Other Expenses. For the third quarter of ~~2022,~~2023, operating expenses of ~~$3,929~~$3,655 million were ~~$635~~$274 million ~~higher~~lower than the ~~$3,294~~$3,929 million incurred during the third quarter of ~~2021.~~2022. The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended September 30, ~~2022~~2023 and ~~2021:~~2022:


		Three Months Ended September 30,					Three Months Ended September 30,
		2022		2021			2023		2022
Lease and Well	Lease and Well	$	3.96	$	3.48	Lease and Well	$	4.02	$	3.96
Transportation Costs	Transportation Costs	3.04		2.82		Transportation Costs	2.61		3.04
Gathering and Processing Costs	Gathering and Processing Costs	1.97		1.87		Gathering and Processing Costs	1.81		1.97
Depreciation, Depletion and Amortization (DD&A) -	Depreciation, Depletion and Amortization (DD&A) -					Depreciation, Depletion and Amortization (DD&A) -
Oil and Gas Properties	Oil and Gas Properties	10.24		11.47		Oil and Gas Properties	9.31		10.24
Other Property, Plant and Equipment	Other Property, Plant and Equipment	0.47		0.46		Other Property, Plant and Equipment	0.47		0.47
General and Administrative (G&A)	General and Administrative (G&A)	1.92		1.83		General and Administrative (G&A)	1.75		1.92
Interest Expense, Net	Interest Expense, Net	0.48		0.62		Interest Expense, Net	0.39		0.48
Total (1)	Total (1)	$	22.08	$	22.55	Total (1)	$	20.36	$	22.08

(1)Total excludes exploration costs, dry hole costs, impairments, marketing costs and taxes other than income.

The primary factors impacting the cost components of per-unit rates of lease and well, transportation costs, ~~gathering and processing costs,~~ DD~~&A, G~~&A and ~~net~~ interest expense, net for the three months ended September 30, ~~2022,~~2023, compared to the same period of ~~2021,~~2022, are set forth below. See "Operating ~~Revenues and Other"~~Revenues" above for a discussion of wellhead volumes.

Lease and well expenses include expenses for EOG-operated properties, as well as expenses billed to EOG from other operators where EOG is not the operator of a property. Lease and well expenses can be divided into the following categories: costs to operate and maintain crude oil and natural gas wells, the cost of workovers and lease and well administrative expenses. Operating and maintenance costs include, among other things, pumping services, produced water disposal, equipment repair and maintenance, compression expense, lease upkeep and fuel and power. Workovers are operations to restore or maintain production from existing wells.

Each of these categories of costs individually fluctuates from time to time as EOG attempts to maintain and increase production while maintaining efficient, safe and environmentally responsible operations. EOG continues to increase its operating activities by drilling new wells in existing and new areas. Operating and maintenance costs within these existing and new areas, as well as the costs of services charged to EOG by vendors, fluctuate over time.

Lease and well expenses of ~~$335~~$369 million for the third quarter of ~~2022~~2023 increased ~~$65~~$34 million from ~~$270~~$335 million for the same prior year period primarily due to increased lease and well administrative expenses ($22 million), increased operating and maintenance costs ($608 million) and increased workover expenditures ($84 million), ~~both~~all in the United States. Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

Transportation costs represent costs associated with the delivery of hydrocarbon products from the lease or an aggregation point on EOG's gathering system to a downstream point of sale. Transportation costs include transportation fees, storage and terminal fees, the cost of compression (the cost of compressing natural gas to meet pipeline pressure requirements), the cost of dehydration (the cost associated with removing water from natural gas to meet pipeline requirements), gathering fees and fuel costs.

Transportation costs of ~~$257~~$240 million for the third quarter of ~~2022 increased $38~~2023 decreased $17 million from ~~$219~~$257 million for the same prior year period primarily due to ~~increased~~decreased transportation costs related to production from the Eagle Ford play ($9 million), the Permian ~~Basin.~~

~~Gathering~~Basin ($5 million) and processing costs represent operating and maintenance expenses and administrative expenses associated with operating EOG's gathering and processing assets as well as natural gas processing fees and certain NGL fractionation fees paid to third parties. EOG pays third parties to process the ~~majority of its natural gas production to extract NGLs.~~Rocky Mountain area ($4 million).

~~-29-~~-28-

Gathering and processing costs increased $22 million to $167 million for the third quarter of 2022 compared to $145 million for the same prior year period primarily due to increased gathering and processing fees related to production from the Permian Basin ($22 million) and increased operating and maintenance expenses related to production from the Permian Basin ($14 million) and the Eagle Ford oil play ($5 million), partially offset by decreased gathering and processing fees related to production from the Eagle Ford oil play ($11 million) and due to the sale of certain legacy natural gas assets in the Rocky Mountain area in the first quarter of 2022 ($9 million).

~~G&A expenses of $162 million for the third quarter of 2022 increased $20 million from $142 million for the same prior year period primarily due to increased professional and other services.~~

DD&A of the cost of proved oil and gas properties is calculated using the unit-of-production method. EOG's DD&A rate and expense are the composite of numerous individual DD&A group calculations. There are several factors that can impact EOG's composite DD&A rate and expense, such as field production profiles, drilling or acquisition of new wells, disposition of existing wells and reserve revisions (upward or downward) primarily related to well performance, economic factors and impairments. Changes to these factors may cause EOG's composite DD&A rate and expense to fluctuate from period to period. DD&A of the cost of other property, plant and equipment is generally calculated using the straight-line depreciation method over the useful lives of the assets.

DD&A expenses for the third quarter of ~~2022~~2023 decreased ~~$21~~$8 million to ~~$906~~$898 million from ~~$927~~$906 million for the same prior year period. DD&A expenses associated with oil and gas properties for the third quarter of ~~2022~~2023 were ~~$24~~$11 million lower than the same prior year period. The decrease primarily reflects decreased unit rates in the United States ($~~108 million) and decreased production in Trinidad ($4~~92 million), partially offset by increased production in the United States ($8978 million) and increased unit rates in Trinidad ($4 million). Unit rates in the United States decreased primarily due to upward reserve revisions related to ~~higher average crude oil, NGL~~favorable well performance, increased ethane recovery and ~~natural gas prices used in the~~ reserve ~~estimation process and to reserves added~~additions at lower costs ~~as a result of increased efficiencies.~~

~~Exploration costs of $35 million for~~per Boe during the ~~third quarter of 2022 decreased $9 million from $44 million for the same prior year period due primarily to decreased geological and geophysical expenditures in the United States.~~quarter.

Interest expense, net of ~~$41~~$36 million for the third quarter of ~~2022~~2023 decreased $7$5 million compared to the same prior year period primarily due to ~~decreased interest expense on certain royalty payments.~~the repayment in March 2023 of the $1,250 million aggregate principal amount of 2.625% Senior Notes due 2023.

Exploration costs of $43 million for the third quarter of 2023 increased $8 million from $35 million for the same prior year period due primarily to increased administrative expenses in the United States.

Impairments include: amortization of unproved oil and gas property costs as well as impairments of proved oil and gas properties; other property, plant and equipment; and other assets. Unproved properties with acquisition costs that are not individually significant are aggregated, and the portion of such costs estimated to be nonproductive is amortized over the remaining lease term. Unproved properties with individually significant acquisition costs are reviewed individually for impairment. When circumstances indicate that a proved property may be impaired, EOG compares expected undiscounted future cash flows at a DD&A group level to the unamortized capitalized cost of the asset. If the expected undiscounted future cash flows, based on EOG's estimates of (and assumptions regarding) future crude oil, NGLs and natural gas prices, operating costs, development expenditures, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated by using the Income Approach described in the Fair Value Measurement Topic of the Financial Accounting Standards Board's Accounting Standards Codification. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.

The following table represents impairments for the third quarter of ~~2022~~2023 and ~~2021~~2022 (in millions):


		Three Months Ended September 30,					Three Months Ended September 30,
		2022		2021			2023		2022
Proved properties	Proved properties	$	45	$	13	Proved properties	$	23	$	45
Unproved properties	Unproved properties	49		69		Unproved properties	30		49

Firm commitment contracts						Firm commitment contracts	1		—
Total	Total	$	94	$	82	Total	$	54	$	94

~~-30-~~

Taxes other than income include severance/production taxes, ad valorem/property taxes, payroll taxes, franchise taxes and other miscellaneous taxes. Severance/production taxes are generally determined based on wellhead revenues, and ad valorem/property taxes are generally determined based on the valuation of the underlying assets.

Taxes other than income for the third quarter of ~~2022~~2023 increased ~~$57~~$7 million to ~~$334~~$341 million ~~(5.5%~~(7.4% of wellhead revenues) from ~~$277~~$334 million ~~(6.8%~~(5.5% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to ~~increased~~state severance tax refunds received in 2022 ($115 million), partially offset by decreased severance/production taxes ($~~145~~95 million) and ~~increased~~decreased ad valorem/property taxes ($~~27 million), partially offset by increased state severance tax refunds ($116~~16 million), all in the United States.

-29-

Other income, net was ~~$40~~$52 million for the third quarter of ~~2022~~2023 compared to other income, net of $6$40 million for the same prior year period. The change of ~~$34~~$12 million in the third quarter of ~~2022~~2023 was primarily due to increased interest income ($3027 million) ~~and higher~~, partially offset by the absence of equity income ~~from~~due to the sale of EOG's equity interest in ammonia ~~plants~~plant investments in Trinidad in the first quarter of 2023 ($49 million).

EOG recognized an income tax provision of $543 million for the third quarter of 2023 compared to an income tax provision of $809 million for the third quarter of 2022, ~~compared to an income tax provision of $334 million for the third quarter of 2021,~~ primarily due to ~~increased~~decreased pretax income. The net effective tax rate for the third quarter of ~~2022~~2023 decreased to ~~22%~~21% from ~~23%~~22% for the third quarter of ~~2021.~~2022.

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

Operating Revenues. During the first nine months of ~~2022,~~2023, operating revenues ~~increased $6,385~~decreased $1,154 million, or ~~51%~~6%, to ~~$18,983~~$17,829 million from ~~$12,598~~$18,983 million for the same period of ~~2021.~~2022. Total wellhead revenues for the first nine months of ~~2022 increased $7,094~~2023 decreased $4,980 million, or ~~66%~~28%, to ~~$17,799~~$12,819 million from ~~$10,705~~$17,799 million for the same period of ~~2021.~~2022. During the first nine months of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$4,215~~$520 million compared to net losses of ~~$1,288~~$4,215 million for the same period of ~~2021.~~2022. Gathering, processing and marketing revenues for the first nine months of ~~2022 increased $2,143~~2023 decreased $866 million, or ~~70%~~17%, to ~~$5,199~~$4,333 million from ~~$3,056~~$5,199 million for the same period of ~~2021.~~2022. Net gains on asset dispositions were ~~$101~~$95 million for the first nine months of ~~2022~~2023 compared to net gains of ~~$46~~$101 million for the same period of ~~2021.~~2022.

~~-31-~~-30-

Wellhead volume and price statistics for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 were as follows:


		Nine Months Ended September 30,						Nine Months Ended September 30,
		2022			2021			2023		2022
Crude Oil and Condensate Volumes (MBbld)	Crude Oil and Condensate Volumes (MBbld)						Crude Oil and Condensate Volumes (MBbld)
United States	United States	459.2			441.3		United States	472.0		459.2
Trinidad	Trinidad	0.7			1.7		Trinidad	0.6		0.7
Other International		—			0.1
Total	Total	459.9			443.1		Total	472.6		459.9
Average Crude Oil and Condensate Prices ($/Bbl) (1)	Average Crude Oil and Condensate Prices ($/Bbl) (1)						Average Crude Oil and Condensate Prices ($/Bbl) (1)
United States	United States	$	101.16		$	65.18	United States	$	78.69	$	101.16
Trinidad	Trinidad	88.84			54.33		Trinidad	68.37		88.84
Other International		—			42.36
Composite	Composite	101.14			65.14		Composite	78.67		101.14
Natural Gas Liquids Volumes (MBbld)	Natural Gas Liquids Volumes (MBbld)						Natural Gas Liquids Volumes (MBbld)
United States	United States	200.6			140.4		United States	219.7		200.6
Total	Total	200.6			140.4		Total	219.7		200.6
Average Natural Gas Liquids Prices ($/Bbl) (1)	Average Natural Gas Liquids Prices ($/Bbl) (1)						Average Natural Gas Liquids Prices ($/Bbl) (1)
United States	United States	$	39.29		$	32.07	United States	$	23.35	$	39.29
Composite		39.29			32.07
Natural Gas Volumes (MMcfd)	Natural Gas Volumes (MMcfd)						Natural Gas Volumes (MMcfd)
United States	United States	1,293			1,170		United States	1,517		1,293
Trinidad	Trinidad	192			221		Trinidad	154		192
Other International		—			12
Total	Total	1,485			1,403		Total	1,671		1,485
Average Natural Gas Prices ($/Mcf) (1)	Average Natural Gas Prices ($/Mcf) (1)						Average Natural Gas Prices ($/Mcf) (1)
United States	United States	$	7.68		$	4.30	United States	$	2.70	$	7.68
Trinidad	Trinidad	4.55		(2)	3.38		Trinidad	3.59		4.55		(2)
Other International		—			5.67
Composite	Composite	7.28			4.17		Composite	2.78		7.28
Crude Oil Equivalent Volumes (MBoed)	Crude Oil Equivalent Volumes (MBoed)						Crude Oil Equivalent Volumes (MBoed)
United States	United States	875.3			776.8		United States	944.6		875.3
Trinidad	Trinidad	32.6			38.5		Trinidad	26.2		32.6
Other International		—			2.0
Total	Total	907.9			817.3		Total	970.8		907.9

Total MMBoe	Total MMBoe	247.8			223.1		Total MMBoe	265.0		247.8

(1) Excludes the impact of financial commodity derivative instruments (see Note 12 to the Condensed Consolidated Financial Statements).

(2) Includes revenue adjustment of $0.96 per Mcf ($0.12 per Mcf of EOG's composite wellhead natural gas price) related to a price adjustment per a provision of the natural gas sales contract with NGC amended in July 2022 for natural gas sales during the period from September 2020 through June 2022.

~~-32-~~-31-

Wellhead crude oil and condensate revenues for the first nine months of ~~2022 increased $4,818~~2023 decreased $2,546 million, or ~~61%~~20%, to ~~$12,697~~$10,151 million from ~~$7,879~~$12,697 million for the same period of ~~2021~~2022 due to a ~~higher~~lower composite average price ($~~4,525~~2,900 million) ~~and~~, partially offset by an increase of ~~16.8~~12.7 MBbld, or 4%3%, in wellhead crude oil and condensate production ($~~293~~354 million). Increased production was primarily in the Permian Basin, partially offset by decreased production in the Eagle Ford ~~oil~~ play and the Rocky Mountain area. EOG's composite wellhead crude oil and condensate price for the first nine months of ~~2022 increased 55%~~2023 decreased 22% to ~~$101.14~~$78.67 per barrel compared to ~~$65.14~~$101.14 per barrel for the same period of ~~2021.~~2022.

NGL revenues for the first nine months of ~~2022 increased $922~~2023 decreased $751 million, or ~~75%~~35%, to ~~$2,151~~$1,400 million from ~~$1,229~~$2,151 million for the same period of ~~2021~~2022 due to a lower composite average price ($955 million), partially offset by an increase of ~~60.2~~19.1 MBbld, or ~~43%~~10%, in NGL deliveries ($~~527 million) and a higher composite average price ($395~~204 million). Increased production was primarily from the Permian ~~Basin.~~Basin, partially offset by decreased production from the Eagle Ford play. EOG's composite NGL price for the first nine months of ~~2022 increased 23%~~2023 decreased 41% to ~~$39.29~~$23.35 per barrel compared to ~~$32.07~~$39.29 per barrel for the same period of ~~2021.~~2022.

Wellhead natural gas revenues for the first nine months of ~~2022 increased $1,354~~2023 decreased $1,683 million, or ~~85%~~57%, to ~~$2,951~~$1,268 million from ~~$1,597~~$2,951 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite ~~wellhead natural gas~~average price ($~~1,262~~2,054 million) ~~and~~, partially offset by an increase in natural gas deliveries ($92371 million). Natural gas deliveries for the first nine months of ~~2022~~2023 increased 82186 MMcfd, or 6%13%, compared to the same period of ~~2021~~2022 due primarily to ~~higher deliveries in the Dorado gas play and~~ increased production of associated natural gas from the Permian Basin and higher deliveries in the Dorado gas play, partially offset by ~~lower natural gas volumes due to the sale of certain legacy natural gas assets in the Rocky Mountain area in the first quarter of 2022,~~ lower natural gas deliveries in Trinidad and ~~lower~~decreased production of associated natural gas ~~volumes associated with~~from the ~~disposition of the China assets in the second quarter of 2021.~~Eagle Ford play. EOG's composite wellhead natural gas price for the first nine months of ~~2022 increased 75%~~2023 decreased 62% to ~~$7.28~~$2.78 per Mcf compared to ~~$4.17~~$7.28 per Mcf for the same period of ~~2021.~~2022.

During the first nine months of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$4,215~~$520 million compared to net losses of ~~$1,288~~$4,215 million for the same period of ~~2021.~~2022. During the first nine months of ~~2022,~~2023, net cash paid for settlements of financial commodity derivative contracts was $130 million. Net cash paid for settlements of financial commodity derivative contracts was $3,257 million of which $1,391 million was related to the early termination of certain contracts. Such early termination payments included $307 million to terminate contracts scheduled to settle in the second half of 2022 and $1,084 million to terminate contracts scheduled to settle after December 31, 2022. Net cash paid for settlements of financial commodity derivative contracts was $516 million for the same period of ~~2021.~~2022.

Gathering, processing and marketing revenues less marketing costs for the first nine months of ~~2022 increased $125~~2023 decreased $35 million as compared to the same period of ~~2021~~2022 primarily due to ~~higher~~lower margins on natural gas marketing activities.

Operating and Other Expenses. For the first nine months of ~~2022,~~2023, operating expenses of ~~$11,870~~$10,730 million were ~~$2,846~~$1,140 million ~~higher~~lower than the ~~$9,024~~$11,870 million incurred during the same period of ~~2021.~~2022. The following table presents the costs per Boe for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021:~~2022:


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Lease and Well	Lease and Well	$	3.94	$	3.63	Lease and Well	$	4.06	$	3.94
Transportation Costs	Transportation Costs	2.94		2.85		Transportation Costs	2.69		2.94
Gathering and Processing Costs	Gathering and Processing Costs	1.87		1.85		Gathering and Processing Costs	1.83		1.87
DD&A -	DD&A -					DD&A -
Oil and Gas Properties	Oil and Gas Properties	10.28		11.79		Oil and Gas Properties	9.19		10.28
Other Property, Plant and Equipment	Other Property, Plant and Equipment	0.47		0.49		Other Property, Plant and Equipment	0.48		0.47
G&A	G&A	1.67		1.67		G&A	1.69		1.67
Interest Expense, Net	Interest Expense, Net	0.55		0.63		Interest Expense, Net	0.43		0.55
Total (1)	Total (1)	$	21.72	$	22.91	Total (1)	$	20.37	$	21.72

(1)Total excludes exploration costs, dry hole costs, impairments, marketing costs and taxes other than income.

~~-33-~~

The primary factors impacting the cost components of per-unit rates of lease and well, transportation costs, gathering and processing costs, DD&A, G&A and ~~G&A~~interest expense, net for the nine months ended September 30, ~~2022,~~2023, compared to the same period of ~~2021~~2022 are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

-32-

Lease and well expenses of ~~$977~~$1,076 million for the first nine months of ~~2022~~2023 increased ~~$167~~$99 million from ~~$810~~$977 million for the same prior year period primarily due to increased operating and maintenance costs in the United States ($~~135~~54 million) and Trinidad ($6 million) and increased ~~workover expenditures ($32 million), both~~lease and well administrative expenses in the United ~~States.~~States ($37 million). Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

Transportation costs of ~~$729~~$712 million for the first nine months of ~~2022 increased $94~~2023 decreased $17 million from ~~$635~~$729 million for the same prior year period primarily due to decreased transportation costs related to production from the Eagle Ford play ($32 million) and the Rocky Mountain area ($9 million), partially offset by increased transportation costs related to production from the Permian Basin ($~~75 million), the Eagle Ford oil play ($14~~18 million) and the Dorado gas play ($76 million).

Gathering and processing costs represent operating and maintenance expenses and administrative expenses associated with operating EOG's gathering and processing assets as well as natural gas processing fees and certain NGL fractionation fees paid to third parties. EOG pays third parties to process the majority of its natural gas production to extract NGLs.

Gathering and processing costs increased ~~$51~~$22 million to ~~$463~~$485 million for the first nine months of ~~2022~~2023 compared to ~~$412~~$463 million for the same prior year period primarily due to increased gathering and processing fees related to production from the Permian Basin ($5420 million) and increased operating and maintenance expenses related to production from the ~~Permian Basin~~Rocky Mountain area ($3411 million) and the ~~Eagle Ford oil play~~Permian Basin ($79 million), partially offset by decreased gathering and processing fees related to production from the ~~Eagle Ford oil play ($28 million) and due to the sale of certain legacy natural gas assets in the~~ Rocky Mountain area ~~in the first quarter of 2022~~ ($~~19 million).~~

~~G&A expenses of $414 million for the first nine months of 2022 increased $42 million from $372 million for the same prior year period primarily due to increased professional and other services ($22~~12 million) and ~~employee-related costs~~decreased operating and maintenance expenses related to production from the Eagle Ford play ($2112 million).

DD&A expenses for the first nine months of ~~2022~~2023 decreased ~~$77~~$102 million to ~~$2,664~~$2,562 million from ~~$2,741~~$2,664 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first nine months of ~~2022~~2023 were ~~$81~~$113 million lower than the same prior year period. The decrease primarily reflects decreased unit rates in the United States ($~~379~~315 million) and ~~in Trinidad ($7 million),~~ decreased production in Trinidad ($~~10 million) and decreased production associated with the disposition of the China assets in the second quarter of 2021 ($5~~9 million), partially offset by increased production in the United States ($~~321~~195 million) and increased unit rates in Trinidad ($10 million). Unit rates in the United States decreased primarily due to upward reserve revisions related to ~~higher average crude oil, NGL~~favorable well performance, increased ethane recovery and ~~natural gas prices used in the reserve estimation process and to~~ reserves added at lower cost per Boe during the year. DD&A expenses associated with other property, plant and equipment for the first nine months of 2023 were $11 million higher than the same prior year period primarily due to an increase in expenses related to gathering and processing assets and equipment.

G&A expenses of $448 million for the first nine months of 2023 increased $34 million from $414 million for the same prior year period primarily due to increased employee-related costs.

Interest expense, net of $113 million for the first nine months of 2023 decreased $24 million compared to the same prior year period primarily due to the repayment in March 2023 of the $1,250 million aggregate principal amount of 2.625% Senior Notes due 2023 ($19 million) and decreased interest expense on certain royalty payments ($7 million).

Exploration costs ~~as a result~~ of $140 million for the first nine months of 2023 increased ~~efficiencies.~~$25 million from $115 million for the same prior year period due primarily to increased geological and geophysical expenditures ($16 million) and increased administrative expenses ($10 million), both in the United States.

The following table represents impairments for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Proved properties	Proved properties	$	59	$	13	Proved properties	$	26	$	59
Unproved properties	Unproved properties	157		155		Unproved properties	95		157
Other assets	Other assets	23		—		Other assets	—		23
Firm commitment contracts	Firm commitment contracts	1		2		Firm commitment contracts	2		1
Total	Total	$	240	$	170	Total	$	123	$	240

~~-34-~~-33-

Taxes other than income for the first nine months of ~~2022 increased $465~~2023 decreased $213 million to ~~$1,196~~$983 million ~~(6.7%~~(7.7% of wellhead revenues) from ~~$731~~$1,196 million ~~(6.8%~~(6.7% of wellhead revenues) for the same prior year period. The ~~increase~~decrease in taxes other than income was primarily due to ~~increased~~decreased severance/production taxes ($~~492 million), increased ad valorem/property taxes ($84 million) and increased payroll taxes ($6~~322 million), partially offset by ~~increased~~decreased state severance tax refunds ($~~118~~112 million), all in the United States.

Other income, net was ~~$66~~$168 million for the first nine months of ~~2022~~2023 compared to other income, net of ~~zero~~$66 million for the same prior year period. The change of ~~$66~~$102 million in the first nine months of ~~2022~~2023 was primarily due to increased interest income ($36134 million) ~~and higher~~, partially offset by the absence of equity income ~~from~~due to the sale of EOG's equity interest in ammonia ~~plants~~plant investments in Trinidad in the first quarter of 2023 ($2737 million).

~~EOG recognized~~EOG's income tax provision of $1,548 million for the first nine months of 2023 decreased from an income tax provision of $1,560 million for the first nine months of ~~2022 compared to an income tax provision of $755 million for the first nine months of 2021, primarily due to increased pretax income.~~2022. The net effective tax rate for the first nine months of ~~2022~~2023 was unchanged from the prior year tax rate of 22%.

Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the nine months ended September 30, ~~2022,~~2023, were funds generated from operations and proceeds from sales of assets. The primary uses of cash were exploration and development expenditures; funds used in operations; dividend payments to stockholders; ~~exploration and development expenditures; net cash paid for settlements~~repayment of ~~financial commodity derivative contracts; net collateral posted for financial commodity derivative contracts;~~maturing debt; purchases of treasury stock; and other property, plant and equipment expenditures. During the first nine months of ~~2022,~~2023, EOG's cash balance ~~increased $63~~decreased $646 million to ~~$5,272~~$5,326 million from ~~$5,209~~$5,972 million at December 31, ~~2021.~~2022.

Net cash provided by operating activities of ~~$7,649~~$8,236 million for the first nine months of ~~2022~~2023 increased ~~$2,024~~$587 million compared to the same period of ~~2021~~2022 primarily due to ~~an increase in wellhead revenues ($7,094 million) and an increase in gathering, processing and marketing revenues less marketing costs ($125 million), partially offset by an increase~~a decrease in net cash paid for settlements of financial commodity derivative contracts ($~~2,741~~3,127 million), ~~an unfavorable change~~a decrease in net cash paid for income taxes ($~~1,284~~1,183 million), ~~an increase~~net cash provided by a change in ~~cash operating expenses~~collateral posted for financial commodity derivative contracts ($~~832~~870 million), and a decrease in net cash used in working capital and other assets and liabilities ($543 million), partially offset by a decrease in ~~the first nine months of 2022~~wellhead revenues ($999 million) compared to net cash used in working capital and other assets and liabilities in the first nine months of 2021 ($590 million) and an increase in net collateral posted for financial commodity derivative contracts ($2384,980 million).

Net cash used in investing activities of ~~$3,659~~$4,841 million for the first nine months of ~~2022~~2023 increased ~~$1,077~~$1,182 million compared to the same period of ~~2021~~2022 due to an increase in additions to oil and gas properties ($701 million), net cash used in working capital associated with investing activities in the first nine months of 2022 ($301 million) compared to net cash provided by working capital associated with investing activities in the first nine months of 2021 ($100635 million), an increase in additions to other property, plant and equipment ($~~101 million) and an increase in other investing activities ($30~~390 million), ~~partially offset by an increase~~a decrease in proceeds from the sale of assets ($~~156~~175 million) and an increase in net cash used in working capital associated with investing activities ($12 million), partially offset by a decrease in other investing activities ($30 million).

Net cash used in financing activities of $4,041 million for the first nine months of 2023 included cash dividend payments ($2,041 million), repayments of long-term debt ($1,250 million), purchases of treasury stock ($728 million) and repayment of finance lease liabilities ($24 million). Net cash used in financing activities of $3,926 million for the first nine months of 2022 included cash dividend payments ($3,821 million), purchases of treasury stock in connection with stock compensation plans ($95 million) and repayment of finance lease liabilities ($27 million). Net cash used in financing activities of $2,079 million for the first nine months of 2021 included cash dividend payments ($1,278 million), repayments of long-term debt ($750 million), purchases of treasury stock in connection with stock compensation plans ($33 million) and repayment of finance lease liabilities ($27 million).

~~-35-~~-34-

Total Expenditures. For the ~~year 2022,~~full-year 2023, EOG's updated budget for exploration and development and other property, plant and equipment expenditures is estimated to range from approximately ~~$4.5~~$5.9 billion to ~~$4.7~~$6.1 billion, excluding acquisitions, non-cash transactions and exploration costs. The table below sets out components of total expenditures for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Nine Months Ended September 30,					Nine Months Ended September 30,
		2022		2021			2023		2022
Expenditure Category	Expenditure Category					Expenditure Category
Capital	Capital					Capital
Exploration and Development Drilling(1)	Exploration and Development Drilling(1)	$	2,599	$	2,097	Exploration and Development Drilling(1)	$	3,619	$	2,599
Facilities	Facilities	291		287		Facilities	373		291
Leasehold Acquisitions ~~(1)~~(2)	Leasehold Acquisitions ~~(1)~~(2)	148		194		Leasehold Acquisitions ~~(1)~~(2)	153		148
Property Acquisitions ~~(2)~~(3)	Property Acquisitions ~~(2)~~(3)	398		99		Property Acquisitions ~~(2)~~(3)	9		398
Capitalized Interest	Capitalized Interest	26		24		Capitalized Interest	24		26
Subtotal	Subtotal	3,462		2,701		Subtotal	4,178		3,462
Exploration Costs	Exploration Costs	115		112		Exploration Costs	140		115
Dry Hole Costs	Dry Hole Costs	41		28		Dry Hole Costs	1		41
Exploration and Development Expenditures	Exploration and Development Expenditures	3,618		2,841		Exploration and Development Expenditures	4,319		3,618
Asset Retirement Costs	Asset Retirement Costs	209		56		Asset Retirement Costs	227		209
Total Exploration and Development Expenditures	Total Exploration and Development Expenditures	3,827		2,897		Total Exploration and Development Expenditures	4,546		3,827
Other Property, Plant and Equipment ~~(3)~~(4)	Other Property, Plant and Equipment ~~(3)~~(4)	248		221		Other Property, Plant and Equipment ~~(3)~~(4)	638		248
Total Expenditures	Total Expenditures	$	4,075	$	3,118	Total Expenditures	$	5,184	$	4,075

(1) Exploration and development drilling included $85 million for the nine-month period ended September 30, 2023, related to non-cash development drilling.

(2) Leasehold acquisitions included ~~$107~~$60 million and ~~$37~~$107 million for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, related to non-cash property exchanges.

~~(2)~~(3) Property acquisitions included $6$9 million and $4$6 million for the nine-month periods ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, related to non-cash property exchanges.

~~(3)~~(4) Other ~~property, plant~~Property, Plant and ~~equipment~~Equipment included ~~$74~~$134 million ~~of non-cash additions~~ for the nine-month period ended September 30, ~~2021, primarily~~2023, related to ~~finance lease transactions for storage facilities.~~the acquisition of a gathering and processing system in the Powder River Basin.

Exploration and development expenditures of ~~$3,618~~$4,319 million for the first nine months of ~~2022~~2023 were ~~$777~~$701 million higher than the same period of ~~2021~~2022 primarily due to increased exploration and development drilling expenditures in the United States ($~~520~~986 million) and increased ~~property acquisitions~~facilities expenditures ($~~299~~82 million), partially offset by decreased ~~leasehold~~property acquisitions ($46389 million) ~~and decreased exploration~~. Exploration and development expenditures for the first nine months of 2023 of $4,319 million consisted of $3,836 million in development drilling ~~expenditures~~and facilities, $450 million in ~~Other International ($21 million).~~exploration, $24 million in capitalized interest and $9 million in property acquisitions. Exploration and development expenditures for the first nine months of 2022 of $3,618 million consisted of $2,822 million in development drilling and facilities, $398 million in property acquisitions, $372 million in exploration and $26 million in capitalized interest. Exploration and development expenditures for the first nine months of 2021 of $2,841 million consisted of $2,299 million in development drilling and facilities, $419 million in exploration, $99 million in property acquisitions and $24 million in capitalized interest.

The level of exploration and development expenditures, including acquisitions, will vary in future periods depending on energy market conditions and other economic factors. EOG believes it has significant flexibility and availability with respect to financing alternatives and the ability to adjust its exploration and development expenditure budget as circumstances warrant. While EOG has certain continuing commitments associated with expenditure plans related to its operations, such commitments are not expected to be material when considered in relation to the total financial capacity of EOG.

~~-36-~~-35-

Financial Commodity Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's ~~2021~~2022 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as ~~Losses~~Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts on the Condensed Consolidated Statements of Income and Comprehensive Income. The related cash flow impact is reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

The total fair value of EOG's financial commodity derivative contracts ~~net of associated collateral posted,~~ was reflected on the Condensed Consolidated Balance Sheets at September 30, ~~2022,~~2023, as a net liability of ~~$642~~$277 million.

As discussed in "Operating Revenues, ~~and Other,~~" the net cash ~~paid for~~received from settlements of financial commodity derivative contracts during the third quarter of 2023 was $23 million and the net cash paid for the settlements of financial commodity derivatives during the first nine months of ~~2022~~2023 was $847 million and $3,257 million, respectively, of which $63 million and $1,391 million, respectively, during the third quarter and first nine months of 2022 was related to the early termination of certain contracts; see the below summary tables for further discussion.$130 million.

Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the period from January 1, ~~2022~~2023 to October ~~28, 2022~~31, 2023 (closed) and outstanding as of October ~~28, 2022.~~31, 2023. Crude oil ~~and NGL~~ volumes are presented in MBbld and prices are presented in $/Bbl. Natural gas volumes are presented in MMBtu per day (MMBtud) and prices are presented in dollars per MMBtu ($/MMBtu).


Crude Oil Financial Price Swap Contracts
		Contracts Sold			Contracts Purchased
Period	Settlement Index	Volume (MBbld)	Weighted Average Price ($/Bbl)		Volume (MBbld)	Weighted Average Price ($/Bbl)

January - March 2023 (closed)	NYMEX West Texas Intermediate (WTI)	95	$	67.90	6	$	102.26
April - May 2023 (closed)	NYMEX WTI	91	67.63		2	98.15
June 2023 (closed)	NYMEX WTI	2	69.10		2	98.15

Natural Gas Financial Price Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price ($/MMBtu)

January - November 2023 (closed)

NYMEX Henry Hub

300

3.36

December 2023

NYMEX Henry Hub

300

3.36

January - December 2024

NYMEX Henry Hub

725

3.07

January - December 2025

NYMEX Henry Hub

725

3.07

~~-37-~~

-36-

Crude Oil Financial Price Swap Contracts
Contracts Sold Contracts Purchased
Period Settlement Index Volume
(MBbld) Weighted Average Price
($/Bbl) Volume (MBbld) Weighted Average Price ($/Bbl)
January - March 2022 (closed) NYMEX West Texas Intermediate (WTI) 140 $ 65.58 — $ —
April - June 2022 (closed) NYMEX WTI 140 65.62 — —
July - September 2022 (closed) NYMEX WTI 140 65.59 — —
October - December 2022 (closed) (1)
NYMEX WTI 53 66.11 — —
October - December 2022 NYMEX WTI 87 65.41 87 88.85
January - March 2023 (closed) (1) (2)
NYMEX WTI 55 67.96 — —
January - March 2023 NYMEX WTI 95 67.90 6 102.26
April - May 2023 (closed) (1)
NYMEX WTI 29 68.28 — —
April - May 2023 NYMEX WTI 91 67.63 2 98.15
June 2023 (closed) (1)
NYMEX WTI 118 67.77 — —
June 2023 NYMEX WTI 2 69.10 2 98.15
July - September 2023 (closed) (1)
NYMEX WTI 100 70.15 — —
October - December 2023 (closed) (1)
NYMEX WTI 69 69.41 — —

Crude Oil Basis Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MBbld) Weighted Average Price Differential
($/Bbl)
January - November 2022 (closed)
NYMEX WTI Roll Differential (1)
125 $ 0.15
December 2022
NYMEX WTI Roll Differential (1)
125 0.15

~~(1) This settlement index is used to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month.~~

~~-38-~~

Natural Gas Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price ($/MMBtu)
January - September 2022 (closed) NYMEX Henry Hub 725 $ 3.57
October - December 2022 (closed) (1)
NYMEX Henry Hub 425 3.05
October - November 2022 (closed) NYMEX Henry Hub 300 4.32
December 2022 NYMEX Henry Hub 300 4.32
January - December 2023 (closed) (1)
NYMEX Henry Hub 425 3.05
January - December 2023 NYMEX Henry Hub 300 3.36
January - December 2024 NYMEX Henry Hub 725 3.07
January - December 2025 NYMEX Henry Hub 725 3.07

Natural Gas Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price Differential
($/MMBtu)

Period

Settlement Index

Volume
(MMBtud in thousands)

Weighted Average Price Differential
($/MMBtu)

January - September 2022 (closed)

NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)

210

0.01

October - December 2022

NYMEX Henry Hub HSC Differential (1)

210

0.01

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

0.01

January - October 2023 (closed)

NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)

135

0.01

November - December 2023

NYMEX Henry Hub HSC Differential

135

0.01

January - December 2024

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2024

NYMEX Henry Hub HSC Differential

0.00

January - December 2025

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2025

NYMEX Henry Hub HSC Differential

0.00

(1) This settlement index is used to fix the differential between pricing at the Houston Ship Channel and NYMEX Henry Hub prices.

In connection with its financial commodity derivative contracts, EOG had ~~$623 million of~~no collateral posted and no collateral held at November ~~2, 2022. EOG expects this collateral to be applied to the settlement of financial commodity derivative contracts if market prices remain above contract prices.~~1, 2023. The amount of posted collateral will increase or decrease based on fluctuations in forward NYMEX WTI and Henry Hub prices.

-37-

~~-39-~~

Information Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, goals, returns and rates of return, budgets, reserves, levels of production, capital expenditures, costs and asset sales, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for future operations, are forward‐looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "aims," "ambition," "initiative," "goal," "may," "will," "focused on," "should" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward‐looking statements. In particular, statements, express or implied, concerning EOG's future financial or operating results and returns or EOG's ability to replace or increase reserves, increase production, generate returns and rates of return, replace or increase drilling locations, reduce or otherwise control drilling, completion and operating costs and capital expenditures, generate cash flows, pay down or refinance indebtedness, achieve, reach or otherwise meet initiatives, plans, goals, ambitions or targets with respect to emissions, other environmental matters, safety matters or other ESG (environmental/social/governance) matters, or pay and/or increase dividends are forward‐looking statements. Forward-looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that ~~these~~such assumptions are accurate or will prove to have been correct or that any of ~~these~~such expectations will be achieved (in full or at all) or will ~~prove to have been correct.~~be achieved on the expected or anticipated timelines. Moreover, EOG's forward-looking statements may be affected by known, unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others:

•the timing, extent and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids (NGLs), natural gas and related commodities;

•the extent to which EOG is successful in its efforts to acquire or discover additional reserves;

•the extent to which EOG is successful in its efforts to (i) economically develop its acreage in, (ii) produce reserves and achieve anticipated production levels and rates of return from, (iii) decrease or otherwise control its drilling, completion and operating costs and capital ~~costs~~expenditures related to, and (iv) maximize reserve recovery from, its existing and future crude oil and natural gas exploration and development projects and associated potential and existing drilling locations;

•the success of EOG's cost-mitigation initiatives and actions in offsetting the impact of inflationary pressures on EOG's operating costs and capital expenditures;

•the extent to which EOG is successful in its efforts to market its production of crude oil and condensate, NGLs and natural gas;

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

•the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, storage, transportation, refining, and export facilities;

•the availability, cost, terms and timing of issuance or execution of mineral licenses and leases and governmental and other permits and rights-of-way, and EOG's ability to retain mineral licenses and leases;

•the impact of, and changes in, government policies, laws and regulations, including climate change-related regulations, policies and initiatives (for example, with respect to air emissions); tax laws and regulations (including, but not limited to, carbon tax and emissions-related legislation); environmental, health and safety laws and regulations relating to disposal of produced water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations affecting the leasing of acreage and permitting for oil and gas drilling and the calculation of royalty payments in respect of oil and gas production; laws and regulations imposing additional permitting and disclosure requirements, additional operating restrictions and conditions or restrictions on drilling and completion operations and on the transportation of crude oil, NGLs and natural gas; laws and regulations with respect to financial derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;

~~-40-~~-38-

•the impact of climate change-related policies and initiatives at the corporate and/or investor community levels and other potential developments related to climate change, such as (but not limited to) changes in consumer and industrial/commercial behavior, preferences and attitudes with respect to the generation and consumption of energy; increased availability of, and increased consumer and industrial/commercial demand for, competing energy sources (including alternative energy sources); technological advances with respect to the generation, transmission, storage and consumption of energy; alternative fuel requirements; energy conservation ~~measures;~~measuresand emissions-related legislation; decreased demand for, and availability of, services and facilities related to the exploration for, and production of, crude oil, NGLs and natural gas; and negative perceptions of the oil and gas industry and, in turn, reputational risks associated with the exploration for, and production of, crude oil, NGLs and natural gas;

•continuing political and social concerns relating to climate change and the greater potential for shareholder activism, governmental inquiries and enforcement actions and litigation and the resulting expenses and potential disruption to EOG's day-to-day operations;

•the extent to which EOG is able to successfully and economically develop, implement and carry out its emissions and other ESG-related initiatives and achieve its related targets and initiatives;

•EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, ~~fully~~ identify and resolve existing and potential ~~problems~~issues with respect to such properties and accurately estimate reserves, production, ~~and~~ drilling, ~~completing~~completion and operating costs and capital expenditures with respect to such properties;

•the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully, economically and in compliance with applicable laws and regulations;

•competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties;

•the availability and cost of, and competition in the oil and gas exploration and production industry for, employees, labor and other personnel, facilities, equipment, materials (such as water, sand, fuel and tubulars) and services;

•the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;

•weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining, compression, storage, transportation, and export facilities;

•the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG;

•EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements;

•the extent to which EOG is successful in its completion of planned asset dispositions;

•the extent and effect of any hedging activities engaged in by EOG;

•the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;

•the duration and economic and financial impact of epidemics, pandemics or other public health ~~issues, including the COVID-19 pandemic;~~issues;

•geopolitical factors and political conditions and developments around the world (such as the imposition of tariffs or trade or other economic sanctions, political instability and armed conflict), including in the areas in which EOG operates;

•the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;

•acts of war and terrorism and responses to these acts; and

•the other factors described under ITEM 1A, Risk Factors of EOG's Annual Report on Form 10-K for the ~~fiscal~~ year ended December 31, ~~2021~~2022, and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.

-39-

In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence or the duration or extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise.

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PART I. FINANCIAL INFORMATION

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

EOG RESOURCES, INC.

EOG's exposure to commodity price risk, interest rate risk and foreign currency exchange rate risk is discussed in (i) the ~~"Commodity~~"Financial Commodity Derivative Transactions," "Financing," "Foreign Currency Exchange Rate Risk" and "Outlook" sections of "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" included in EOG's Annual Report on Form 10-K for the year ended December 31, ~~2021,~~2022, filed on February ~~24,~~23, 2023 (EOG's 2022 ~~(EOG's 2021~~ Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements included in EOG's ~~2021~~2022 Annual Report. For updated information regarding EOG's financial commodity derivative contracts and physical commodity contracts, see (i) Note 12, "Risk Management Activities," to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q; (ii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Operating ~~Revenues and Other"~~Revenues" in this Quarterly Report on Form 10-Q; and (iii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity - Financial Commodity Derivative Transactions" in this Quarterly Report on Form 10-Q.

ITEM 4. CONTROLS AND PROCEDURES

EOG RESOURCES, INC.

Disclosure Controls and Procedures. EOG's management, with the participation of EOG's principal executive officer and principal financial officer, evaluated the effectiveness of EOG's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act)) as of the end of the period covered by this Quarterly Report on Form 10-Q (Evaluation Date). Based on this evaluation, EOG's principal executive officer and principal financial officer have concluded that EOG's disclosure controls and procedures were effective as of the Evaluation Date in ensuring that information that is required to be disclosed in the reports EOG files or furnishes under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in the United States Securities and Exchange Commission's rules and forms and (ii) accumulated and communicated to EOG's management, as appropriate, to allow timely decisions regarding required disclosure.

Internal Control Over Financial Reporting. There were no changes in EOG's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) promulgated under the Exchange Act) that occurred during the quarterly period covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, EOG's internal control over financial reporting.

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PART II. OTHER INFORMATION

EOG RESOURCES, INC.

ITEM 1. LEGAL PROCEEDINGS

See Part I, Item 1, Note 8 to Condensed Consolidated Financial Statements, which is incorporated herein by reference.

Item 103 of Regulation S-K promulgated under the Securities Exchange Act of 1934 (as amended, Exchange Act) requires disclosure regarding certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that EOG reasonably believes will exceed a specified threshold. Pursuant to ~~recent amendments to this~~such item, EOG will be using a threshold of $1 million for purposes of determining whether disclosure of any such proceedings is required. EOG believes proceedings under this threshold are not material to EOG's business and financial condition. Applying this threshold, there are no environmental proceedings to disclose for the quarter ended September 30, ~~2022.~~2023.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table sets forth, for the periods indicated, EOG's share repurchase activity:

Period
Total
Number of
Shares Purchased (1)
Average
Price Paid Per Share Total Value of
Shares Purchased as
Part of Publicly
Announced Plans or Programs
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (2)
July 1, 2022 - July 31, 2022 6,149 $ 108.69 — $ 5,000,000,000
August 1, 2022 - August 31, 2022 18,473 115.99 — $ 5,000,000,000
September 1, 2022 - September 30, 2022 321,946 105.79 — $ 5,000,000,000
Total 346,568 106.39 —


Period	Total Number of Shares Purchased (1)	Average Price Paid Per Share		Total Value of Shares Purchased as Part of Publicly Announced Plans or Programs (2)		Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (2)(3)


July 1, 2023 - July 31, 2023	18,912	$	124.28	$	—	$	4,389,743,068
August 1, 2023 - August 31, 2023	22,266	129.88		—		$	4,389,743,068
September 1, 2023 - September 30, 2023	822,107	125.64		60,875,448		$	4,328,867,620
Total	863,285	125.72		60,875,448

(1)~~The 346,568 total~~Includes 494,804 shares ~~for~~repurchased during the quarter ended September 30, ~~2022, consist solely~~2023, at an average price of $123.03 per share (inclusive of commissions and transaction fees), pursuant to the November 2021 Authorization (as defined and further discussed below); such repurchases count against the November 2021 Authorization. Also includes 368,481 total shares that were withheld by or returned to EOG during the quarter ended September 30, 2023, at an average price of $129.34 per share, (i) in satisfaction of tax withholding obligations that arose upon the exercise of employee stock options or stock-settled stock appreciation rights or the vesting of restricted stock, restricted stock unit or performance unit grants or (ii) in payment of the exercise price of employee stock ~~options. These~~options (such shares do not count against the November 2021 ~~Authorization (as defined and further discussed below)~~Authorization).

(2)Effective November 4, 2021, EOG's Board of Directors (Board) ~~(i)~~ established a new share repurchase authorization ~~to allow~~that allows for the repurchase by EOG of up to $5 billion of its common stock (November 2021 Authorization). As of the date of this filing, (i) EOG has repurchased an aggregate 6,204,038 shares at a total cost of $671,132,380 (inclusive of commissions and transaction fees) under the November 2021 Authorization and (ii) an additional $4,328,867,620 of shares may be purchased under the November 2021 Authorization.

(3)Under the ~~new authorization,~~November 2021 Authorization, EOG may repurchase shares from time to time, at management's discretion, in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. The timing and amount of repurchases ~~if any, will be~~is at the discretion of EOG's management and ~~will depend~~depends on a variety of factors, including the ~~then-trading~~trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares ~~will be~~are held as treasury shares and ~~will be~~are available for general corporate purposes. The November 2021 Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended or terminated by the Board at any time. ~~EOG has not repurchased any shares under the November 2021 Authorization as of the date of this filing.~~

~~ITEM 4.MINE SAFETY DISCLOSURES~~

The information concerning mine safety violations and other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95 to this Quarterly Report on Form 10-Q.

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ITEM 5. OTHER INFORMATION

~~It is currently anticipated that EOG's~~Trading Plans/Arrangements. During the quarter ended September 30, 2023, ~~annual meeting~~no director or Section 16 officer of ~~stockholders (2023 Annual Meeting) will be held on May 24, 2023, at a time and location to be determined and specified~~EOG adopted or terminated any Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (in each case, as defined in ~~EOG's proxy statement for the 2023 Annual Meeting.~~

Because the 2023 Annual Meeting is anticipated to be held more than 30 days after the anniversary of EOG's 2022 annual meeting of stockholders (2022 Annual Meeting), EOG has set December 2, 2022 as the new deadline for submission of stockholder proposals for inclusion in EOG's proxy statement for the 2023 Annual Meeting pursuant to Rule 14a-8Item 408(a) of Regulation ~~14A under the Exchange Act (Rule 14a-8)~~S-K).Specifically, to be considered for inclusion in EOG's proxy statement for the 2023 Annual Meeting, stockholder proposals submitted under Rule 14a-8 must be received by us, addressed to our Corporate Secretary (Michael P. Donaldson), at our principal executive offices at 1111 Bagby, Sky Lobby 2, Houston, Texas 77002, no later than December 2, 2022. Such proposals must also comply with the remaining requirements of Rule 14a-8.

For director nominations or other business (other than stockholder proposals under Rule 14a-8) to be brought before an annual meeting of stockholders by any of our stockholders, timely notice, in writing, must be given to our Corporate Secretary.As previously disclosed in EOG's proxy statement for the 2022 Annual Meeting, to be timely with respect to our 2023 Annual Meeting, notice shall be delivered, in writing, to our Corporate Secretary (Michael P. Donaldson) at our principal executive offices at 1111 Bagby, Sky Lobby 2, Houston, Texas 77002, no earlier than the close of business on November 10, 2022 and no later than the close of business on December 12, 2022.

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ITEM 6. EXHIBITS


Exhibit No.		Description

3.1(a)	-	Restated Certificate of Incorporation, dated September 3, 1987 (incorporated by reference to Exhibit 3.1(a) to EOG's Annual Report on Form 10-K for the year ended December 31, 2008) (SEC File No. 001-09743).

3.1(b)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 5, 1993 (incorporated by reference to Exhibit 4.1(b) to EOG's Registration Statement on Form S-8, SEC File No. 33-52201, filed February 8, 1994).

3.1(c)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated June 14, 1994 (incorporated by reference to Exhibit 4.1(c) to EOG's Registration Statement on Form S-8, SEC File No. 33-58103, filed March 15, 1995).

3.1(d)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated June 11, 1996 (incorporated by reference to Exhibit 3(d) to EOG's Registration Statement on Form S-3, SEC File No. 333-09919, filed August 9, 1996).

3.1(e)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 7, 1997 (incorporated by reference to Exhibit 3(e) to EOG's Registration Statement on Form S-3, SEC File No. 333-44785, filed January 23, 1998).

3.1(f)	-	Certificate of Ownership and Merger Merging EOG Resources, Inc. into Enron Oil & Gas Company, dated August 26, 1999 (incorporated by reference to Exhibit 3.1(f) to EOG's Annual Report on Form 10-K for the year ended December 31, 1999) (SEC File No. 001-09743).

3.1(g)	-	Certificate of Designations of Series E Junior Participating Preferred Stock, dated February 14, 2000 (incorporated by reference to Exhibit 2 to EOG's Registration Statement on Form 8-A, SEC File No. 001-09743, filed February 18, 2000).

3.1(h)	-	Certificate of Elimination of the Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series A, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(j) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).

3.1(i)	-	Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series C, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(k) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).

3.1(j)	-	Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series D, dated February 24, 2005 (incorporated by reference to Exhibit 3.1(k) to EOG's Annual Report on Form 10-K for the year ended December 31, 2004) (SEC File No. 001-09743).

3.1(k)	-	Amended Certificate of Designations of Series E Junior Participating Preferred Stock, dated March 7, 2005 (incorporated by reference to Exhibit 3.1(m) to EOG's Annual Report on Form 10-K for the year ended December 31, 2007) (SEC File No. 001-09743).

3.1(l)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 3, 2005 (incorporated by reference to Exhibit 3.1(l) to EOG's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005) (SEC File No. 001-09743).

3.1(m)	-	Certificate of Elimination of Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series B, dated March 6, 2008 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed March 6, 2008) (SEC File No. 001-09743).

3.1(n)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated April 28, 2017 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed May 2, 2017) (SEC File No. 001-09743).

~~3.2~~3.2(a)	-	Bylaws, dated August 23, 1989, as amended and restated effective as of September 22, 2015 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed September 28, 2015) (SEC File No. 001-09743).
3.2(b)	-	Bylaws, dated August 23, 1989, as amended and restated effective as of February 23, 2023 (incorporated by reference to Exhibit 3.2(b) to EOG's Annual Report on Form 10-K for the year ended December 31, 2022) (SEC File No. 001-09743).

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Exhibit No.		Description

10.1	-	Form of Restricted Stock Award Agreement for EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (applicable to grants made on or after September 15, 2023).

10.2	-	Form of Restricted Stock Unit Award Agreement for EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (applicable to grants made on or after September 15, 2023).

10.3	-	Form of Restricted Stock Unit with Performance-Based Conditions ("Performance Unit") Award Agreement for EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (applicable to grants made on or after September ~~29, 2022) (Exhibit 10.1 to EOG's Current Report on Form 8-K, filed October 4, 2022) (SEC File No. 001-09743)~~15, 2023).

~~10.2~~10.4	-	Retirement Notice and Letter, dated September 11, 2023, by and between EOG ~~Resources, Inc. Amended~~ and ~~Restated Annual Bonus Plan (effective as of January 1, 2022) (Exhibit 10.2 to EOG's Current Report on Form 8-K, filed October 4, 2022) (SEC File No. 001-09743).~~Kenneth W. Boedeker.

31.1	-	Section 302 Certification of Periodic Report of Principal Executive Officer.

31.2	-	Section 302 Certification of Periodic Report of Principal Financial Officer.

32.1	-	Section 906 Certification of Periodic Report of Principal Executive Officer.

32.2	-	Section 906 Certification of Periodic Report of Principal Financial Officer.

95	-	~~Mine Safety Disclosure Exhibit.~~

101.INS	-	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

*101.SCH	-	Inline XBRL Schema Document.

*101.CAL	-	Inline XBRL Calculation Linkbase Document.

*101.DEF	-	Inline XBRL Definition Linkbase Document.

*101.LAB	-	Inline XBRL Label Linkbase Document.

*101.PRE	-	Inline XBRL Presentation Linkbase Document.

104	-	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three Months and Nine Months ~~ended~~Ended September 30, ~~2022~~2023 and ~~2021,~~2022, (ii) the Condensed Consolidated Balance Sheets - September 30, ~~2022~~2023 and December 31, ~~2021,~~2022, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three Months and Nine Months Ended September 30, ~~2022~~2023 and ~~2021,~~2022, (iv) the Condensed Consolidated Statements of Cash Flows - Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~2022 and (v) the Notes to Condensed Consolidated Financial Statements.

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SIGNATURES

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


			EOG RESOURCES, INC.
			(Registrant)



Date:	November ~~3, 2022~~2, 2023	By:	/s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

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