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 June 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	~~586,044,522~~582,260,898	(as of July ~~28, 2022)~~27, 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 Six Months Ended June 30, ~~2022~~2023 and ~~2021~~2022

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

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

Condensed Consolidated Statements of Cash Flows - Six Months Ended June 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

ITEM 4.

Controls and Procedures

PART II.

OTHER INFORMATION

ITEM 1.

Legal Proceedings

ITEM 2.

Unregistered Sales of Equity Securities and Use of Proceeds

ITEM 4.5.

~~Mine Safety Disclosures~~Other Information

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 June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 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	$	4,699	$	2,699	$	8,588	$	4,950	Crude Oil and Condensate	$	3,252	$	4,699	$	6,434	$	8,588
Natural Gas Liquids	Natural Gas Liquids	777		367		1,458		681		Natural Gas Liquids	409		777		899		1,458
Natural Gas	Natural Gas	1,000		404		1,716		1,029		Natural Gas	334		1,000		851		1,716
Losses on Mark-to-Market Financial Commodity Derivative Contracts		(1,377)		(427)		(4,197)		(794)
Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts										Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts	101		(1,377)		477		(4,197)
Gathering, Processing and Marketing	Gathering, Processing and Marketing	2,169		1,022		3,638		1,870		Gathering, Processing and Marketing	1,465		2,169		2,855		3,638
Gains on Asset Dispositions, Net		97		51		122		45
Gains (Losses) on Asset Dispositions, Net										Gains (Losses) on Asset Dispositions, Net	(9)		97		60		122
Other, Net	Other, Net	42		23		65		52		Other, Net	21		42		41		65
Total	Total	7,407		4,139		11,390		7,833		Total	5,573		7,407		11,617		11,390
Operating Expenses	Operating Expenses									Operating Expenses
Lease and Well	Lease and Well	324		270		642		540		Lease and Well	348		324		707		642
Transportation Costs	Transportation Costs	244		214		472		416		Transportation Costs	236		244		472		472
Gathering and Processing Costs	Gathering and Processing Costs	152		128		296		267		Gathering and Processing Costs	160		152		319		296
Exploration Costs	Exploration Costs	35		35		80		68		Exploration Costs	47		35		97		80
Dry Hole Costs	Dry Hole Costs	20		13		23		24		Dry Hole Costs	—		20		1		23
Impairments	Impairments	91		44		146		88		Impairments	35		91		69		146
Marketing Costs	Marketing Costs	2,127		991		3,410		1,829		Marketing Costs	1,456		2,127		2,817		3,410
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	911		914		1,758		1,814		Depreciation, Depletion and Amortization	866		911		1,664		1,758
General and Administrative	General and Administrative	128		120		252		230		General and Administrative	142		128		287		252
Taxes Other Than Income	Taxes Other Than Income	472		239		862		454		Taxes Other Than Income	313		472		642		862
Total	Total	4,504		2,968		7,941		5,730		Total	3,603		4,504		7,075		7,941
Operating Income	Operating Income	2,903		1,171		3,449		2,103		Operating Income	1,970		2,903		4,542		3,449
Other Income (Expense), Net		27		(2)		26		(6)
Other Income, Net										Other Income, Net	51		27		116		26
Income Before Interest Expense and Income Taxes	Income Before Interest Expense and Income Taxes	2,930		1,169		3,475		2,097		Income Before Interest Expense and Income Taxes	2,021		2,930		4,658		3,475
Interest Expense, Net	Interest Expense, Net	48		45		96		92		Interest Expense, Net	35		48		77		96
Income Before Income Taxes	Income Before Income Taxes	2,882		1,124		3,379		2,005		Income Before Income Taxes	1,986		2,882		4,581		3,379
Income Tax Provision	Income Tax Provision	644		217		751		421		Income Tax Provision	433		644		1,005		751
Net Income	Net Income	$	2,238	$	907	$	2,628	$	1,584	Net Income	$	1,553	$	2,238	$	3,576	$	2,628
Net Income Per Share	Net Income Per Share									Net Income Per Share
Basic	Basic	$	3.84	$	1.56	$	4.52	$	2.73	Basic	$	2.68	$	3.84	$	6.14	$	4.52
Diluted	Diluted	$	3.81	$	1.55	$	4.48	$	2.72	Diluted	$	2.66	$	3.81	$	6.10	$	4.48
Average Number of Common Shares	Average Number of Common Shares									Average Number of Common Shares
Basic	Basic	583		580		582		580		Basic	580		583		582		582
Diluted	Diluted	588		584		587		583		Diluted	584		588		586		587
Comprehensive Income	Comprehensive Income									Comprehensive Income
Net Income	Net Income	$	2,238	$	907	$	2,628	$	1,584	Net Income	$	1,553	$	2,238	$	3,576	$	2,628
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss)									Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	Foreign Currency Translation Adjustments	2		(1)		1		(3)		Foreign Currency Translation Adjustments	(1)		2		(1)		1
Other, Net of Tax	Other, Net of Tax	(1)		—		(1)		—		Other, Net of Tax	—		(1)		—		(1)
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss)	1		(1)		—		(3)		Other Comprehensive Income (Loss)	(1)		1		(1)		—
Comprehensive Income	Comprehensive Income	$	2,239	$	906	$	2,628	$	1,581	Comprehensive Income	$	1,552	$	2,239	$	3,575	$	2,628

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)


		June 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and Cash Equivalents	Cash and Cash Equivalents	$	3,073	$	5,209	Cash and Cash Equivalents	$	4,764	$	5,972
Accounts Receivable, Net	Accounts Receivable, Net	3,735		2,335		Accounts Receivable, Net	2,263		2,774
Inventories	Inventories	739		584		Inventories	1,355		1,058
Assets from Price Risk Management Activities		1		—
Income Taxes Receivable						Income Taxes Receivable	1		97
Other	Other	605		456		Other	523		574
Total	Total	8,153		8,584		Total	8,906		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)	66,098		67,644		Oil and Gas Properties (Successful Efforts Method)	69,178		67,322
Other Property, Plant and Equipment	Other Property, Plant and Equipment	4,862		4,753		Other Property, Plant and Equipment	5,282		4,786
Total Property, Plant and Equipment	Total Property, Plant and Equipment	70,960		72,397		Total Property, Plant and Equipment	74,460		72,108
Less: Accumulated Depreciation, Depletion and Amortization	Less: Accumulated Depreciation, Depletion and Amortization	(42,113)		(43,971)		Less: Accumulated Depreciation, Depletion and Amortization	(43,550)		(42,679)
Total Property, Plant and Equipment, Net	Total Property, Plant and Equipment, Net	28,847		28,426		Total Property, Plant and Equipment, Net	30,910		29,429
Deferred Income Taxes	Deferred Income Taxes	12		11		Deferred Income Taxes	33		33
Other Assets	Other Assets	1,127		1,215		Other Assets	1,638		1,434
Total Assets	Total Assets	$	38,139	$	38,236	Total Assets	$	41,487	$	41,371
LIABILITIES AND STOCKHOLDERS' EQUITY	LIABILITIES AND STOCKHOLDERS' EQUITY					LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts Payable	Accounts Payable	$	2,896	$	2,242	Accounts Payable	$	2,205	$	2,532
Accrued Taxes Payable	Accrued Taxes Payable	594		518		Accrued Taxes Payable	425		405
Dividends Payable	Dividends Payable	437		436		Dividends Payable	478		482
Liabilities from Price Risk Management Activities	Liabilities from Price Risk Management Activities	79		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	216		240		Current Portion of Operating Lease Liabilities	335		296
Other	Other	264		300		Other	232		346
Total	Total	5,768		4,042		Total	3,731		5,513

Long-Term Debt	Long-Term Debt	3,809		5,072		Long-Term Debt	3,780		3,795
Other Liabilities	Other Liabilities	2,067		2,193		Other Liabilities	2,581		2,574
Deferred Income Taxes	Deferred Income Taxes	4,183		4,749		Deferred Income Taxes	5,138		4,710
Commitments and Contingencies (Note 8)	Commitments and Contingencies (Note 8)	0		0		Commitments and Contingencies (Note 8)

Stockholders' Equity	Stockholders' Equity					Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 586,391,670 Shares Issued at June 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 June 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 June 30, 2023 and 588,396,757 Shares Issued at December 31, 2022	206		206
Additional Paid in Capital	Additional Paid in Capital	6,128		6,087		Additional Paid in Capital	6,257		6,187
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss	(12)		(12)		Accumulated Other Comprehensive Loss	(9)		(8)
Retained Earnings	Retained Earnings	16,028		15,919		Retained Earnings	20,497		18,472
Common Stock Held in Treasury, 344,705 Shares at June 30, 2022 and 257,268 Shares at December 31, 2021		(38)		(20)
Common Stock Held in Treasury, 6,426,802 Shares at June 30, 2023 and 700,281 Shares at December 31, 2022						Common Stock Held in Treasury, 6,426,802 Shares at June 30, 2023 and 700,281 Shares at December 31, 2022	(694)		(78)
Total Stockholders' Equity	Total Stockholders' Equity	22,312		22,180		Total Stockholders' Equity	26,257		24,779
Total Liabilities and Stockholders' Equity	Total Liabilities and Stockholders' Equity	$	38,139	$	38,236	Total Liabilities and Stockholders' Equity	$	41,487	$	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 March 31, 2022		$	206	$	6,095	$	(13)	$	15,283	$	(31)	$	21,540
Balance at March 31, 2023														Balance at March 31, 2023	$	206	$	6,219	$	(8)	$	19,423	$	(393)	$	25,447
Net Income	Net Income	—		—		—		2,238		—		2,238		Net Income	—		—		—		1,553		—		1,553
Common Stock Dividends Declared, $2.55 Per Share		—		—		—		(1,493)		—		(1,493)
Other Comprehensive Income		—		—		1		—		—		1
Common Stock Dividends Declared, $0.825 Per Share														Common Stock Dividends Declared, $0.825 Per Share	—		—		—		(479)		—		(479)
Other Comprehensive Loss														Other Comprehensive Loss	—		—		(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		—		(11)		—		—		(6)		(17)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		1		—		—		(1)		—		Restricted Stock and Restricted Stock Units, Net	—		(3)		—		—		3		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		30		—		—		—		30		Stock-Based Compensation Expenses	—		35		—		—		—		35
Treasury Stock Issued as Compensation		—		—		—		—		—		—
Balance at June 30, 2022		$	206	$	6,128	$	(12)	$	16,028	$	(38)	$	22,312
Treasury Stock Repurchased														Treasury Stock Repurchased	—		—		—		—		(305)		(305)
Change in Treasury Stock - Stock Compensation Plans, Net														Change in Treasury Stock - Stock Compensation Plans, Net	—		6		—		—		1		7
Balance at June 30, 2023														Balance at June 30, 2023	$	206	$	6,257	$	(9)	$	20,497	$	(694)	$	26,257


		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 March 31, 2021		$	206	$	5,979	$	(14)	$	14,606	$	(15)	$	20,762
Balance at March 31, 2022														Balance at March 31, 2022	$	206	$	6,095	$	(13)	$	15,283	$	(31)	$	21,540
Net Income	Net Income	—		—		—		907		—		907		Net Income	—		—		—		2,238		—		2,238
Common Stock Dividends Declared, $1.4125 Per Share		—		—		—		(824)		—		(824)
Other Comprehensive Loss		—		—		(1)		—		—		(1)
Common Stock Dividends Declared, $2.55 Per Share														Common Stock Dividends Declared, $2.55 Per Share	—		—		—		(1,493)		—		(1,493)
Other Comprehensive Income														Other Comprehensive Income	—		—		1		—		—		1
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	—		(2)		—		—		(1)		(3)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(11)		—		—		(6)		(17)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		—		—		—		—		—		Restricted Stock and Restricted Stock Units, Net	—		1		—		—		(1)		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		31		—		—		—		31		Stock-Based Compensation Expenses	—		30		—		—		—		30
Treasury Stock Issued as Compensation		—		—		—		—		—		—
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

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 Income (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	—		—		—		2,628		—		2,628		Net Income	—		—		—		3,576		—		3,576
Common Stock Dividends Declared, $4.30 Per Share		—		—		—		(2,519)		—		(2,519)
Common Stock Dividends Declared, $2.65 Per Share														Common Stock Dividends Declared, $2.65 Per Share	—		—		—		(1,551)		—		(1,551)
Other Comprehensive Loss	Other Comprehensive Loss	—		—		—		—		—		—		Other Comprehensive Loss	—		—		(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		—		(35)		—		—		(20)		(55)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—		Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		65		—		—		—		65		Stock-Based Compensation Expenses	—		69		—		—		—		69
Treasury Stock Issued as Compensation		—		—		—		—		—		—
Balance at June 30, 2022		$	206	$	6,128	$	(12)	$	16,028	$	(38)	$	22,312
Treasury Stock Repurchased														Treasury Stock Repurchased	—		—		—		—		(615)		(615)
Change in Treasury Stock - Stock Compensation Plans, Net														Change in Treasury Stock - Stock Compensation Plans, Net	—		3		—		—		(3)		—
Balance at June 30, 2023														Balance at June 30, 2023	$	206	$	6,257	$	(9)	$	20,497	$	(694)	$	26,257


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Income (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	—		—		—		1,584		—		1,584		Net Income	—		—		—		2,628		—		2,628
Common Stock Dividends Declared, $1.825 Per Share		—		—		—		(1,065)		—		(1,065)
Common Stock Dividends Declared, $4.30 Per Share														Common Stock Dividends Declared, $4.30 Per Share	—		—		—		(2,519)		—		(2,519)
Other Comprehensive Loss	Other Comprehensive Loss	—		—		(3)		—		—		(3)		Other Comprehensive Loss	—		—		—		—		—		—
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	—		(2)		—		—		(10)		(12)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(35)		—		—		(20)		(55)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(1)		—		—		1		—		Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		66		—		—		—		66		Stock-Based Compensation Expenses	—		65		—		—		—		65
Treasury Stock Issued as Compensation	Treasury Stock Issued as Compensation	—		—		—		—		—		—		Treasury Stock Issued as Compensation	—		—		—		—		—		—
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

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)


		Six Months Ended June 30,					Six Months Ended June 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	$	2,628	$	1,584	Net Income	$	3,576	$	2,628
Items Not Requiring (Providing) Cash	Items Not Requiring (Providing) Cash					Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	1,758		1,814		Depreciation, Depletion and Amortization	1,664		1,758
Impairments	Impairments	146		88		Impairments	69		146
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	65		66		Stock-Based Compensation Expenses	69		65
Deferred Income Taxes	Deferred Income Taxes	(567)		(133)		Deferred Income Taxes	428		(567)
Gains on Asset Dispositions, Net	Gains on Asset Dispositions, Net	(122)		(45)		Gains on Asset Dispositions, Net	(60)		(122)
Other, Net	Other, Net	(10)		13		Other, Net	6		(10)
Dry Hole Costs	Dry Hole Costs	23		24		Dry Hole Costs	1		23
Mark-to-Market Financial Commodity Derivative Contracts	Mark-to-Market Financial Commodity Derivative Contracts					Mark-to-Market Financial Commodity Derivative Contracts
Total Losses		4,197		794
(Gains) Losses, Net						(Gains) Losses, Net	(477)		4,197
Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(2,410)		(223)		Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(153)		(2,410)
Other, Net	Other, Net	21		1		Other, Net	(1)		21
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	(1,400)		(494)		Accounts Receivable	475		(1,400)
Inventories	Inventories	(171)		101		Inventories	(303)		(171)
Accounts Payable	Accounts Payable	389		183		Accounts Payable	(308)		389
Accrued Taxes Payable	Accrued Taxes Payable	77		80		Accrued Taxes Payable	20		77
Other Assets	Other Assets	(142)		(222)		Other Assets	95		(142)
Other Liabilities	Other Liabilities	(1,817)		(57)		Other Liabilities	146		(1,817)
Changes in Components of Working Capital Associated with Investing Activities	Changes in Components of Working Capital Associated with Investing Activities	211		(145)		Changes in Components of Working Capital Associated with Investing Activities	285		211
Net Cash Provided by Operating Activities	Net Cash Provided by Operating Activities	2,876		3,429		Net Cash Provided by Operating Activities	5,532		2,876
Investing Cash Flows	Investing Cash Flows					Investing Cash Flows
Additions to Oil and Gas Properties	Additions to Oil and Gas Properties	(2,288)		(1,843)		Additions to Oil and Gas Properties	(2,646)		(2,288)
Additions to Other Property, Plant and Equipment	Additions to Other Property, Plant and Equipment	(145)		(97)		Additions to Other Property, Plant and Equipment	(499)		(145)
Proceeds from Sales of Assets	Proceeds from Sales of Assets	231		146		Proceeds from Sales of Assets	121		231
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	(211)		145		Changes in Components of Working Capital Associated with Investing Activities	(285)		(211)
Net Cash Used in Investing Activities	Net Cash Used in Investing Activities	(2,443)		(1,649)		Net Cash Used in Investing Activities	(3,309)		(2,443)
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	(2,509)		(458)		Dividends Paid	(1,547)		(2,509)
Treasury Stock Purchased	Treasury Stock Purchased	(58)		(12)		Treasury Stock Purchased	(619)		(58)
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	9		17
Debt Issuance Costs						Debt Issuance Costs	(8)		—
Repayment of Finance Lease Liabilities	Repayment of Finance Lease Liabilities	(19)		(18)		Repayment of Finance Lease Liabilities	(16)		(19)
Net Cash Used in Financing Activities	Net Cash Used in Financing Activities	(2,569)		(1,229)		Net Cash Used in Financing Activities	(3,431)		(2,569)
Effect of Exchange Rate Changes on Cash	Effect of Exchange Rate Changes on Cash	—		—		Effect of Exchange Rate Changes on Cash	—		—
Increase (Decrease) in Cash and Cash Equivalents		(2,136)		551
Decrease in Cash and Cash Equivalents						Decrease in Cash and Cash Equivalents	(1,208)		(2,136)
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	$	3,073	$	3,880	Cash and Cash Equivalents at End of Period	$	4,764	$	3,073

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 six months ended June 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 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
June 30, Six Months Ended
June 30,
2022 2021 2022 2021
Lease and Well $ 10 $ 11 $ 23 $ 25
Gathering and Processing Costs 1 1 2 1
Exploration Costs 5 5 10 11
General and Administrative 14 14 30 29
Total $ 30 $ 31 $ 65 $ 66

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 June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Lease and Well	$	11	$	10	$	23	$	23
Gathering and Processing Costs	1		1		2		2
Exploration Costs	5		5		10		10
General and Administrative	18		14		34		30
Total	$	35	$	30	$	69	$	65

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 June 30, ~~2022,~~2023, approximately 1817 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.

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 $8$6 million and $9$8 million during the three months ended June 30, ~~2022~~2023 and ~~2021,~~2022, respectively, and ~~$17~~$12 million and ~~$19~~$17 million during the six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

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


		Stock Options/SARs						ESPP							Stock Options/SARs			ESPP
		Six Months Ended June 30,						Six Months Ended June 30,							Six Months Ended June 30,			Six Months Ended June 30,
		2022			2021			2022			2021				2022			2023			2022
Weighted Average Fair Value of Grants	Weighted Average Fair Value of Grants	$	28.30		$	20.73		$	23.07		$	14.69		Weighted Average Fair Value of Grants	$	28.30		$	32.31		$	23.07
Expected Volatility	Expected Volatility	42.20		%	46.40		%	39.72		%	54.99		%	Expected Volatility	42.20		%	42.97		%	39.72		%
Risk-Free Interest Rate	Risk-Free Interest Rate	0.89		%	0.36		%	0.22		%	0.09		%	Risk-Free Interest Rate	0.89		%	4.66		%	0.22		%
Dividend Yield	Dividend Yield	3.28		%	2.87		%	3.32		%	3.41		%	Dividend Yield	3.28		%	2.47		%	3.32		%
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.

-9-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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


		Six Months Ended June 30, 2022			Six Months Ended June 30, 2021				Six Months Ended June 30, 2023			Six Months Ended June 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		14	64.97		Granted	—	—		2	97.64
Exercised (1)	Exercised (1)	(3,928)	93.12		(239)	69.85		Exercised (1)	(300)	77.26		(3,928)	93.12
Forfeited	Forfeited	(137)	87.54		(234)	91.54		Forfeited	(57)	87.49		(137)	87.54
Outstanding at June 30 (2)	Outstanding at June 30 (2)	5,906	$	78.49	9,727	$	84.23	Outstanding at June 30 (2)	3,868	$	77.37	5,906	$	78.49
Vested or Expected to Vest (3)	Vested or Expected to Vest (3)	5,603	$	79.15	9,421	$	84.91	Vested or Expected to Vest (3)	3,727	$	77.74	5,603	$	79.15
Exercisable at June 30 (4)	Exercisable at June 30 (4)	2,305	$	97.46	6,023	$	97.08	Exercisable at June 30 (4)	2,178	$	84.87	2,305	$	97.46

(1)The total intrinsic value of stock options/SARs exercised during the six months ended June 30, 2023 and 2022 ~~and 2021~~ was ~~$108~~$13 million and $3$108 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 June 30, 2023 and 2022 ~~and 2021~~ was ~~$202~~$150 million and ~~$114~~$202 million, respectively. At June 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was ~~4.5~~3.7 years and ~~3.8~~4.5 years, respectively.

(3)The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2023 and 2022 ~~and 2021~~ was ~~$189~~$143 million and ~~$106~~$189 million, respectively. At June 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was ~~4.4~~3.6 years and ~~3.8~~4.4 years, respectively.

(4)The total intrinsic value of stock options/SARs exercisable at June 30, 2023 and 2022 ~~and 2021~~ was ~~$44~~$71 million and ~~$16~~$44 million, respectively. At both June 30, ~~2022~~2023 and ~~2021,~~2022, the weighted average remaining contractual life was 2.7 years.

At June 30, ~~2022,~~2023, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled ~~$46~~$22 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.6~~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 ~~$20~~$27 million and ~~$21~~$20 million for the three months ended June 30, 2023 and 2022, respectively, and ~~2021, respectively,~~$52 million and $45 million for ~~both~~ the six months ended June 30, 2023 and 2022, ~~and 2021.~~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 six-month periods ended June 30, ~~2022~~2023 and ~~2021~~2022 (shares and units in thousands):


		Six Months Ended June 30, 2022			Six Months Ended June 30, 2021				Six Months Ended June 30, 2023			Six Months Ended June 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	48	115.48		45	72.56		Granted	81	117.05		48	115.48
Released (1)	Released (1)	(780)	91.98		(523)	87.61		Released (1)	(71)	70.07		(780)	91.98
Forfeited	Forfeited	(85)	66.23		(47)	70.24		Forfeited	(67)	83.26		(85)	66.23
Outstanding at June 30 (2)	Outstanding at June 30 (2)	3,863	$	65.45	4,217	$	73.43	Outstanding at June 30 (2)	4,056	$	81.63	3,863	$	65.45

(1)The total intrinsic value of restricted stock and restricted stock units released during the six months ended June 30, 2023 and 2022, ~~and 2021~~ was ~~$91~~$8 million and ~~$38~~$91 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 June 30, 2023 and 2022, ~~and 2021~~ was ~~$427~~$464 million and ~~$352~~$427 million, respectively.

At June 30, ~~2022,~~2023, unrecognized compensation expense related to restricted stock and restricted stock units totaled ~~$151~~$238 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.3 years.

Performance Units. EOG grants Performance Units annually to its executive officers without cost to them. AsFor the grants made prior to September 2022, as more fully discussed in the grant agreements, the applicable performance metric ~~applicable to the Performance Units~~ is EOG's total shareholder return (TSR) over a three-year performance period relative to the ~~total shareholder return~~TSR over the same period of a designated group of peer ~~companies (Performance Period).~~companies. Upon the application of the applicable performance multiple at the completion of the ~~Performance Period,~~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 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 $2 million ~~and $1 million~~ for both the three months ended June 30, 2023 and 2022, and ~~2021, respectively,~~$5 million and $3 ~~million and $2~~ million for the six months ended June 30, 2023 and 2022, ~~and 2021,~~ respectively.

-11-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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

Six Months Ended
June 30, 2022 Six Months Ended
June 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 — — 8 55.69
Granted for Performance Multiple (1)
— — 19 113.81
Released (2)
(57) 136.74 (98) 113.81
Forfeited for Performance Multiple (3)
(56) 136.74 — —
Outstanding at June 30 (4)
566 (5) $ 74.60 542 $ 84.23


	Six Months Ended June 30, 2023				Six Months Ended June 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	—		—		—	—
Released (1)	(86)		79.98		(57)	136.74
Forfeited for Performance Multiple (2)	(86)		79.98		(56)	136.74
Outstanding at June 30 (3)	516	(4)	$	85.10	566	$	74.60

(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 $6$7 million for the six months ended June 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 June 30, ~~2022~~2023 and ~~2021~~2022, was approximately ~~$62~~$59 million and ~~$45~~$62 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 ~~1,132~~1,031 Performance Units could be outstanding.

At June 30, ~~2022,~~2023, unrecognized compensation expense related to Performance Units totaled ~~$10~~$12 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.7 years.

3. Net Income Per Share

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 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	$	2,238	$	907	$	2,628	$	1,584	Net Income	$	1,553	$	2,238	$	3,576	$	2,628
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		580		582		580		Weighted Average Shares	580		583		582		582
Potential Dilutive Common Shares -	Potential Dilutive Common Shares -									Potential Dilutive Common Shares -
Stock Options/SARs/ESPP	Stock Options/SARs/ESPP	2		1		2		1		Stock Options/SARs/ESPP	1		2		1		2
Restricted Stock/Units and Performance Units	Restricted Stock/Units and Performance Units	3		3		3		2		Restricted Stock/Units and Performance Units	3		3		3		3
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	588		584		587		583		Adjusted Diluted Weighted Average Shares	584		588		586		587
Net Income Per Share	Net Income Per Share									Net Income Per Share
Basic	Basic	$	3.84	$	1.56	$	4.52	$	2.73	Basic	$	2.68	$	3.84	$	6.14	$	4.52
Diluted	Diluted	$	3.81	$	1.55	$	4.48	$	2.72	Diluted	$	2.66	$	3.81	$	6.10	$	4.48

~~-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 ~~and 5 million~~ for both the three-month periods ended June 30, 2023 and 2022, and ~~2021, respectively, and were~~ 1 million ~~and 7 million shares~~ for both the six-month periods ended June 30, ~~2022~~2023 and ~~2021, respectively.~~2022.

-12-

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 six-month periods ended June 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Interest (1)	Interest (1)	$	86	$	102	Interest (1)	$	93	$	86
Income Taxes, Net of Refunds Received	Income Taxes, Net of Refunds Received	$	1,428	$	507	Income Taxes, Net of Refunds Received	$	487	$	1,428

(1)Net of capitalized interest of $16 million and $15 million for ~~both~~ the six months ended June 30, 2023 and 2022, ~~and 2021.~~respectively.

EOG's accrued capital expenditures and amounts recorded within accounts payable at June 30, 2023 and 2022 ~~and 2021~~ were ~~$534~~$722 million and ~~$445~~$534 million, respectively.

Non-cash investing activities for the six months ended June 30, ~~2022~~2023 and ~~2021,~~2022, included additions of ~~$84~~$103 million and ~~$25~~$84 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the six months ended June 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 six months ended June 30, 2023 and 2022, included ~~the~~ net ~~use~~cash received of $324 million and net cash used of $1,766 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-~~

~~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 six-month periods ended June 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 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	$	7,338	$	3,995	$	11,252	$	7,601	United States	$	5,520	$	7,338	$	11,461	$	11,252
Trinidad	Trinidad	69		81		138		157		Trinidad	52		69		155		138
Other International (1)	Other International (1)	—		63		—		75		Other International (1)	1		—		1		—
Total	Total	$	7,407	$	4,139	$	11,390	$	7,833	Total	$	5,573	$	7,407	$	11,617	$	11,390
Operating Income (Loss)	Operating Income (Loss)									Operating Income (Loss)
United States	United States	$	2,885	$	1,077	$	3,404	$	1,967	United States	$	1,961	$	2,885	$	4,473	$	3,404
Trinidad	Trinidad	25		41		59		84		Trinidad	16		25		82		59
Other International (1)	Other International (1)	(7)		53		(14)		52		Other International (1)	(7)		(7)		(13)		(14)
Total	Total	2,903		1,171		3,449		2,103		Total	1,970		2,903		4,542		3,449
Reconciling Items	Reconciling Items									Reconciling Items
Other Income (Expense), Net		27		(2)		26		(6)
Other Income, Net										Other Income, Net	51		27		116		26
Interest Expense, Net	Interest Expense, Net	(48)		(45)		(96)		(92)		Interest Expense, Net	(35)		(48)		(77)		(96)
Income Before Income Taxes	Income Before Income Taxes	$	2,882	$	1,124	$	3,379	$	2,005	Income Before Income Taxes	$	1,986	$	2,882	$	4,581	$	3,379

(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.

-13-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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


		At June 30, 2022		At December 31, 2021			At June 30, 2023		At December 31, 2022
Total Assets	Total Assets					Total Assets
United States	United States	$	37,271	$	37,436	United States	$	40,400	$	40,349
Trinidad	Trinidad	723		637		Trinidad	967		879
Other International (1)	Other International (1)	145		163		Other International (1)	120		143
Total	Total	$	38,139	$	38,236	Total	$	41,487	$	41,371

~~-14-~~

~~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 six-month periods ended June 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Six Months Ended June 30,					Six Months Ended June 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	47		40		Liabilities Incurred	18		47
Liabilities Settled (1)	Liabilities Settled (1)	(151)		(55)		Liabilities Settled (1)	(50)		(151)
Accretion	Accretion	20		22		Accretion	25		20
Revisions	Revisions	3		3		Revisions	3		3
Foreign Currency Translation	Foreign Currency Translation	(1)		—		Foreign Currency Translation	2		(1)
Carrying Amount at June 30	Carrying Amount at June 30	$	1,149	$	1,227	Carrying Amount at June 30	$	1,326	$	1,149

Current Portion	Current Portion	$	43	$	47	Current Portion	$	37	$	43
Noncurrent Portion	Noncurrent Portion	$	1,106	$	1,180	Noncurrent Portion	$	1,289	$	1,106

(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.

-14-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

7. Exploratory Well Costs

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


	Six Months Ended June 30, ~~2022~~2023
Balance at January 1	$	715
Additions Pending the Determination of Proved Reserves	4057
Reclassifications to Proved Properties	~~(12)~~(14)
Costs Charged to Expense~~(1)~~	~~(19)~~(1)
Balance at June 30	$	1657


	Six Months Ended June 30, 2023
Capitalized exploratory well costs that have been capitalized for a period of one year or less	$	56
Capitalized exploratory well costs that have been capitalized for a period greater than one year (1)	1
Balance at June 30	$	57

Number of exploratory wells that have been capitalized for a period greater than one year	1

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

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

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 $28 million and $25 million for ~~both~~ the six months ended June 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.

-15-

EOG RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

10. Long-Term Debt and Common Stock

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

~~At June 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 replaces 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 June 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 June 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), had there been any amounts borrowed under the ~~Agreement~~New Facility at June 30, ~~2022,~~2023, would have been ~~2.69%~~6.14% and ~~4.75%~~8.25%, respectively.

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 months and six months ended June 30, 2023, EOG repurchased 2.8 million and 5.7 million shares of common stock, respectively, for approximately $300 million and $610 million (inclusive of transaction fees and commissions), respectively, pursuant to the November 2021 Authorization. As of June 30, 2023, approximately $4.4 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 three and six months ended June 30, 2023, are $5 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 ~~payable~~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.~~

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

17, 2023.

-16-

EOG RESOURCES, INC.

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

(Unaudited)

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

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 June 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 June 30, 2022
At June 30, 2023										At June 30, 2023
Financial Assets:	Financial Assets:									Financial Assets:
Natural Gas Basis Swaps	Natural Gas Basis Swaps	$	—	$	14	$	—	$	14	Natural Gas Basis Swaps	$	—	$	7	$	—	$	7
Crude Oil Swaps		—		2		—		2
Financial Liabilities:	Financial Liabilities:									Financial Liabilities:
Crude Oil Swaps		—		1,040		—		1,040
Natural Gas Swaps	Natural Gas Swaps	—		948		—		948		Natural Gas Swaps	—		303		—		303
Crude Oil Roll Differential Swaps		—		57		—		57

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 June 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.

-17-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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.

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~~ June 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 ~~$4,881~~$3,526 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 six-month period ended June 30, ~~2022~~2023 (closed) and outstanding as of June 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 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 - February 2023 (closed) (1)
NYMEX WTI 7 69.51 — —
January - February 2023 NYMEX WTI 143 67.84 6 102.26
March 2023 (closed) (1)
NYMEX WTI 37 67.35 — —
March 2023 NYMEX WTI 113 68.11 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.

~~-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 - July 2022 (closed)
NYMEX WTI Roll Differential (1)
125 $ 0.15
August - 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 - July 2023 (closed)

NYMEX Henry Hub

300

3.36

August - 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 Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price
($/MMBtu)
January - July 2022 (closed) NYMEX Henry Hub 725 $ 3.57
August - September 2022 NYMEX Henry Hub 725 3.57
October - December 2022 (closed) (1)
NYMEX Henry Hub 425 3.05
October - 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 - June 2022 (closed)

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

210

(0.01)

July - December 2022

NYMEX Henry Hub HSC Differential (1)

210

(0.01)

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

(0.01)

January - June 2023 (closed)

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

135

0.01

July - 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 Location on Balance Sheet. The following table sets forth the amounts and classification of EOG's outstanding financial commodity derivative instruments at June 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 June 30, 2022 December 31, 2021
Asset Derivatives
Crude oil and natural gas derivative contracts -
Current Portion
Assets from Price Risk Management Activities (1)
$ 1 $ —
Noncurrent Portion
Other Assets (2)
— 6
Liability Derivatives
Crude oil and natural gas derivative contracts -
Current portion
Liabilities from Price Risk Management Activities (3)
79 269
Noncurrent portion
Other Liabilities (4)
45 37

Fair Value at

Description

Location on Balance Sheet

June 30, 2023

December 31, 2022

Liability Derivatives

Crude oil, NGLs and natural gas derivative contracts -

Current portion

Liabilities from Price Risk Management Activities (1)

169

Noncurrent portion

Other Liabilities (2)

274

371

(1) ~~The current portion of Assets from Price Risk Management Activities consists of gross assets of $2 million, partially offset by gross liabilities of $1 million, at June 30, 2022.~~

~~(2) 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.~~

~~(3)~~ The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$1,357~~$28 million, partially offset by gross assets of ~~$10~~$6 million and no collateral posted ~~with counterparties of $1,268 million~~ at June 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.

~~(4)~~(2) The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$687~~$275 million, partially offset by gross assets of $4$1 million and no collateral posted ~~with counterparties of $638 million~~ at June 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 June 30, ~~2022~~2023 and December 31, ~~2021.~~2022. EOG had ~~$1,906 million of~~no collateral posted and no collateral held at June 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 June 30, 2022,~~2022. EOG had ~~$1,529 million of~~no collateral posted and no collateral held at August ~~3, 2022.~~2, 2023.

~~-21-~~

13. Acquisitions and Divestitures

During the six months ended June 30, ~~2022.~~2023, EOG paid cash of $135 million, primarily to acquire a gathering and processing system in the Powder River Basin. Additionally, during the six months ended June 30, 2023, EOG recognized net gains on asset dispositions of $60 million and received proceeds of $121 million, primarily due to the sale of EOG's equity interest in ammonia plant investments in Trinidad, along with the sale of certain legacy assets in the Texas Panhandle.

During the six months ended June 30, 2022, EOG paid cash for property acquisitions of $351 million in the United States. Additionally, during the six months ended June 30, 2022, EOG recognized net gains on asset dispositions of $122 million and received proceeds of ~~approximately~~ $231 million, primarily due to the sale of certain legacy natural gas assets in the Rocky Mountain area and producing properties in the Mid-Continent area.

During the six months ended June 30, 2021, EOG paid cash for property acquisitions of $92 million in the United States. Additionally, during the six months ended June 30, 2021, EOG recognized net gains on asset dispositions of $45 million and received proceeds of approximately $146 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. 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 six months of ~~2022,~~2023, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were ~~$101.44~~$74.92 per barrel and ~~$6.05~~$2.76 per million British thermal units (MMBtu), respectively, representing ~~increases~~decreases of ~~64%~~26% and ~~119%~~54%, 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~~Inflation Considerations; Availability of Materials, Labor & Services. Beginning in ~~crude oil~~the second half of 2021 and ~~natural gas prices during~~continuing, to a lesser degree, through the first ~~six~~three months of ~~2022 were due~~2023, EOG, similar to ~~several factors, including~~other companies in its industry, has experienced inflationary pressures on its operating and capital costs - namely the ~~continued recovery in~~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 ~~crude oil, natural gas~~fuel and ~~NGLs from the impacts~~steel; (iii) increased demand for drilling and completion services coupled with a limited number of ~~the COVID-19 pandemic; low worldwide inventory levels; continued supply restraint by OPEC+ (a consortium of OPEC (Organization of Petroleum Exporting Countries)~~available service providers, resulting in increased competition for such services among EOG and ~~certain non-OPEC global producers);~~other companies in its industry; (iv) labor shortages; and ~~the impact resulting from~~(v) other factors, including the ongoing conflict between Russia and ~~Ukraine.~~the Ukraine which began in late February 2022. Beginning in the second quarter of 2023, EOG has seen these inflationary pressures diminish and, in certain circumstances, seen a decline in prices. However, the market for such materials, services and labor continues to fluctuate and, as a result, the timing and impact of any price changes on EOG's future operating and capital costs is uncertain.

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 approximately 10 percent in its fiscal year 2023 well costs (i.e., its costs for drilling, completions and well-site facilities) versus fiscal year 2022. Accordingly, such increase in EOG's fiscal year 2023 well costs did not have a material impact on EOG's second quarter 2023 cash flows, and EOG currently does not expect such increase to have a material impact on its full-year 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 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 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.

~~-23-~~

During the first six 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) ~~resulting from supply chain disruptions, increased demand, labor shortages and other factors, including the ongoing conflict between Russia and Ukraine.~~. 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 six months of ~~2022~~2023 and ~~2021,~~2022, respectively. During the first six 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 March 2021,~~ EOG ~~signed a farmout agreement with Heritage, which allows EOG~~expects to ~~earn a 65% working interest~~commence drilling in ~~a portion~~the third quarter of 2023 from the ~~contract area (EOG Area) governed by~~recently completed platform in the ~~Trinidad Northern Area License. The EOG Area is located offshore the southwest coast of Trinidad. In~~Modified U(a) Block where it expects to complete three development wells and one exploratory well from this platform in 2023. Additionally, in the first half of ~~2022,~~2023, EOG ~~commenced drilling of one net exploratory well, which was determined to be unsuccessful.~~

~~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.~~

~~EOG continues to make progress on~~completed the design ~~and fabrication of a~~phase for the platform and related facilities ~~for its previously announced discovery~~ in the ~~Modified U(a) Block. In~~Mento Area and expects to make significant construction progress during the second half of ~~2022,~~2023.

Also, in the first half of 2023, EOG ~~expects to install the platform together with the related facilities and drill two net exploratory wells and one net development well.~~sold its equity interest in its ammonia plant investments.

Other International. In ~~Australia, in~~ November 2021, a subsidiary of EOG was granted an exploration permit for the WA-488-P Block, located offshore Western Australia. In ~~2022,~~the first half of 2023, EOG ~~continues~~continued to prepare for the drilling of an exploration well which is expected to commence in ~~2023.~~2024, subject to statutory 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 ~~$4.3~~$5.8 billion to ~~$4.7~~$6.2 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 -~~tubulars) through efficiency gains; see the above related ~~discussion) through efficiency gains.~~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 ~~expects~~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.

~~-24-~~

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 ~~19%~~13% and 17% at ~~both~~ June 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 June 30, ~~2022,~~2023, EOG maintained a strong financial and liquidity position, including ~~$3.1~~$4.8 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 replaces 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 payable on September 29, 2022, to stockholders of record as of September 15, 2022.~~

Cash Return Framework. ~~Also on May 5, 2022,~~ EOG ~~announced the addition of~~maintains quantitative guidance toas part of 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.For ~~related~~ discussion regarding our payment of dividends, see ITEM 1A, Risk Factors, and ITEM 5, Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities, of EOG's 2022 Annual Report. For discussion regarding our share repurchases conducted during the second quarter of 2023 and our share repurchase authorization, see Part II, Item 2., Unregistered Sales of Equity Securities and Use of Proceeds, in 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.

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

-23-

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 months and six months ended June 30, 2023, EOG repurchased 2.8 million and 5.7 million shares of common stock, respectively, for approximately $300 million and $610 million (inclusive of transaction fees and commissions), respectively, pursuant to the November 2021 Authorization. As of June 30, 2023, approximately $4.4 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 three and six months ended June 30, 2023, are $5 million of estimated federal excise taxes.

-24-

Results of Operations

The following review of operations for the three months ended June 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.

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

Operating ~~Revenues and Other.~~Revenues. During the second quarter of ~~2022,~~2023, operating revenues ~~increased $3,268~~decreased $1,834 million, or ~~79%~~25%, to ~~$7,407~~$5,573 million from ~~$4,139~~$7,407 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 second quarter of ~~2022 increased $3,006~~2023 decreased $2,481 million, or ~~87%~~38%, to ~~$6,476~~$3,995 million from ~~$3,470~~$6,476 million for the same period of ~~2021.~~2022. EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$1,377~~$101 million for the second quarter of ~~2022~~2023 compared to net losses of ~~$427~~$1,377 million for the same period of ~~2021.~~2022. Gathering, processing and marketing revenues for the second quarter of ~~2022 increased $1,147~~2023 decreased $704 million, or ~~112%~~32%, to ~~$2,169~~$1,465 million from ~~$1,022~~$2,169 million for the same period of ~~2021.~~2022. Net ~~gains~~losses on asset dispositions were ~~$97~~$9 million for the second quarter of ~~2022~~2023 compared to net gains of ~~$51~~$97 million for the same period of ~~2021.~~2022.

-25-

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


		Three Months Ended June 30,					Three Months Ended June 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	463.5		446.9		United States	476.0		463.5
Trinidad	Trinidad	0.6		1.7		Trinidad	0.6		0.6
Other International (2)		—		—
Total	Total	464.1		448.6		Total	476.6		464.1
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	$	111.26	$	66.16	United States	$	74.98	$	111.26
Trinidad	Trinidad	98.29		56.26		Trinidad	64.88		98.29
Other International (2)		—		55.56
Composite	Composite	111.25		66.12		Composite	74.97		111.25
Natural Gas Liquids Volumes (MBbld) (1)	Natural Gas Liquids Volumes (MBbld) (1)					Natural Gas Liquids Volumes (MBbld) (1)
United States	United States	201.9		138.5		United States	215.7		201.9
Total	Total	201.9		138.5		Total	215.7		201.9
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	$	42.28	$	29.15	United States	$	20.85	$	42.28
Composite		42.28		29.15
Natural Gas Volumes (MMcfd) (1)	Natural Gas Volumes (MMcfd) (1)					Natural Gas Volumes (MMcfd) (1)
United States	United States	1,324		1,199		United States	1,513		1,324
Trinidad	Trinidad	204		233		Trinidad	155		204
Other International (2)		—		13
Total	Total	1,528		1,445		Total	1,668		1,528
Average Natural Gas Prices ($/Mcf) (3)
Average Natural Gas Prices ($/Mcf) (2)						Average Natural Gas Prices ($/Mcf) (2)
United States	United States	$	7.77	$	2.99	United States	$	2.07	$	7.77
Trinidad	Trinidad	3.42		3.37		Trinidad	3.45		3.42
Other International (2)		—		5.69
Composite	Composite	7.19		3.07		Composite	2.20		7.19
Crude Oil Equivalent Volumes (MBoed) (4)
Crude Oil Equivalent Volumes (MBoed) (3)						Crude Oil Equivalent Volumes (MBoed) (3)
United States	United States	886.1		785.2		United States	943.8		886.1
Trinidad	Trinidad	34.6		40.6		Trinidad	26.5		34.6
Other International (2)		—		2.2
Total	Total	920.7		828.0		Total	970.3		920.7

Total MMBoe (4)		83.8		75.3
Total MMBoe (3)						Total MMBoe (3)	88.3		83.8

(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,~~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.

-26-

Wellhead crude oil and condensate revenues for the second quarter of ~~2022 increased $2,000~~2023 decreased $1,447 million, or ~~74%~~31%, to ~~$4,699~~$3,252 million from ~~$2,699~~$4,699 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite average price ($~~1,901~~1,568 million) ~~and~~, partially offset by an increase of ~~15.5~~12.5 MBbld, or 3%, in wellhead crude oil and condensate production ($99121 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 second quarter of ~~2022 increased 68%~~2023 decreased 33% to ~~$111.25~~$74.97 per barrel compared to ~~$66.12~~$111.25 per barrel for the same period of ~~2021.~~2022.

NGL revenues for the second quarter of ~~2022 increased $410~~2023 decreased $368 million, or ~~112%~~47%, to ~~$777~~$409 million from ~~$367~~$777 million for the same period of ~~2021~~2022 due to a ~~higher~~lower composite average price ($~~241~~419 million) ~~and~~, partially offset by an increase of ~~63.4~~13.8 MBbld, or ~~46%~~7%, in NGL deliveries ($~~169~~51 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 second quarter of ~~2022 increased 45%~~2023 decreased 51% to ~~$42.28~~$20.85 per barrel compared to ~~$29.15~~$42.28 per barrel for the same period of ~~2021.~~2022.

Wellhead natural gas revenues for the second quarter of ~~2022 increased $596~~2023 decreased $666 million, or ~~148%~~67%, to ~~$1,000~~$334 million from ~~$404~~$1,000 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite average ~~composite~~ price ($~~571~~752 million) ~~and~~, partially offset by an increase in natural gas deliveries ($2586 million). Natural gas deliveries for the second quarter of ~~2022~~2023 increased 83140 MMcfd, or 6%9%, 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 second quarter of ~~2022 increased 134%~~2023 decreased 69% to ~~$7.19~~$2.20 per Mcf compared to ~~$3.07~~$7.19 per Mcf for the same period of ~~2021.~~2022.

During the second quarter of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$1,377~~$101 million compared to net losses of ~~$427~~$1,377 million for the same period of ~~2021.~~2022. During the second quarter of ~~2022,~~2023, net cash paid for settlements of financial commodity derivative contracts was ~~$2,114~~$30 million ~~of which $1,328 million was related~~compared 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 $1,021 million to terminate contracts scheduled to settle after December 31, 2022. Netnet cash paid for settlements of financial commodity derivative contracts ~~was $193~~of $2,114 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 second quarter of ~~2022 increased $11~~2023 decreased $33 million as compared to the same period of ~~2021~~2022 primarily due to ~~higher margins on natural gas marketing activities, partially offset by~~ lower margins on crude oil marketing activities.

-27-

Operating and Other Expenses. For the second quarter of ~~2022,~~2023, operating expenses of ~~$4,504~~$3,603 million were ~~$1,536~~$901 million ~~higher~~lower than the ~~$2,968~~$4,504 million incurred during the second quarter of ~~2021.~~2022. The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended June 30, ~~2022~~2023 and ~~2021:~~2022:


		Three Months Ended June 30,					Three Months Ended June 30,
		2022		2021			2023		2022
Lease and Well	Lease and Well	$	3.87	$	3.58	Lease and Well	$	3.94	$	3.87
Transportation Costs	Transportation Costs	2.91		2.84		Transportation Costs	2.67		2.91
Gathering and Processing Costs	Gathering and Processing Costs	1.81		1.70		Gathering and Processing Costs	1.81		1.81
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	10.42		11.63		Oil and Gas Properties	9.30		10.42
Other Property, Plant and Equipment	Other Property, Plant and Equipment	0.45		0.50		Other Property, Plant and Equipment	0.51		0.45
General and Administrative (G&A)	General and Administrative (G&A)	1.53		1.59		General and Administrative (G&A)	1.61		1.53
Interest Expense, Net	Interest Expense, Net	0.57		0.60		Interest Expense, Net	0.40		0.57
Total (1)	Total (1)	$	21.56	$	22.44	Total (1)	$	20.24	$	21.56

(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 ~~G&A~~interest expense, net for the three months ended June 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, ~~salt~~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 ~~$324~~$348 million for the second quarter of ~~2022~~2023 increased ~~$54~~$24 million from ~~$270~~$324 million for the same prior year period primarily due to increased operating and maintenance costs ($4120 million) and increased lease and well administrative expenses ($6 million), partially offset by decreased workover expenditures ($135 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 ~~$244~~$236 million for the second quarter of ~~2022 increased $30~~2023 decreased $8 million from ~~$214~~$244 million for the same prior year period primarily due to decreased transportation costs related to production from the Eagle Ford play ($12 million), partially offset by increased transportation costs related to production from the Permian Basin ($~~18 million), the Eagle Ford oil play ($7 million) and the Dorado gas play ($5~~6 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.

-28-

Gathering and processing costs increased ~~$24~~$8 million to ~~$152~~$160 million for the second quarter of ~~2022~~2023 compared to ~~$128~~$152 million for the same prior year period primarily due to increased gathering and processing fees ($6 million) related to production from the Permian Basin and increased operating and maintenance expenses ($176 million) ~~and increased~~related to production from the Rocky Mountain area, partially offset by decreased operating and maintenance expenses related to production from the ~~Permian Basin ($12 million) and the~~ Eagle Ford ~~oil~~ play ($96 million).

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 second quarter of 2023 decreased $45 million to $866 million from $911 million for the same prior year period. DD&A expenses associated with oil and gas properties for the second quarter of 2023 were $53 million lower than the same prior year period. The decrease primarily reflects decreased unit rates in the United States ($110 million), partially offset by increased production in the United States ($55 million). Unit rates in the United States decreased ~~gathering and processing fees~~primarily due to upward reserve revisions related to ~~production from~~favorable well performance, increased ethane recovery and reserve additions at lower costs per Boe during the ~~Eagle Ford oil play ($8 million) and due to the sale of certain legacy natural gas assets in the Rocky Mountain area in the first quarter of 2022 ($8 million).~~quarter.

G&A expenses of ~~$128~~$142 million for the second quarter of ~~2022~~2023 increased $8$14 million from ~~$120~~$128 million for the same prior year period primarily due to increased employee-related costs.

Interest expense, net of $35 million for the second quarter of 2023 decreased $13 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 ($9 million) and decreased interest expense on certain royalty payments ($4 million).

Exploration costs of $47 million for the second quarter of 2023 increased $12 million from $35 million for the same prior year period due primarily to increased geological and geophysical expenditures 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 second quarter of ~~2022~~2023 and ~~2021~~2022 (in millions):


		Three Months Ended June 30,					Three Months Ended June 30,
		2022		2021			2023		2022
Proved properties	Proved properties	$	13	$	—	Proved properties	$	1	$	13
Unproved properties	Unproved properties	54		43		Unproved properties	33		54
Other assets	Other assets	23		—		Other assets	—		23
Firm commitment contracts	Firm commitment contracts	1		1		Firm commitment contracts	1		1

Total	Total	$	91	$	44	Total	$	35	$	91

-29-

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 second quarter of ~~2022 increased $233~~2023 decreased $159 million to ~~$472~~$313 million ~~(7.3%~~(7.8% of wellhead revenues) from ~~$239~~$472 million ~~(6.9%~~(7.3% of wellhead revenues) for the same prior year period. The ~~increase~~decrease in taxes other than income was primarily due to ~~increased~~decreased severance/production taxes ($~~215~~172 million) and increased state severance tax refunds ($3 million), partially offset by increased ad valorem/property taxes ($1917 million), all in the United States.

Other income, net was ~~$27~~$51 million for the second quarter of ~~2022~~2023 compared to other ~~expense,~~income, net of $2$27 million for the same prior year period. The change of ~~$29~~$24 million in the second quarter of ~~2022~~2023 was primarily due to ~~a decrease~~increased interest income ($47 million), partially offset by the absence of equity income due to the sale of EOG's equity interest in ammonia plant investments in Trinidad in the first quarter of 2023 ($15 million) and increased deferred compensation expense ($~~13 million), higher equity income from ammonia plants in Trinidad ($12 million) and increased interest income ($6~~8 million).

EOG recognized an income tax provision of $433 million for the second quarter of 2023 compared to an income tax provision of $644 million for the second quarter of 2022, ~~compared to an income tax provision of $217 million for the second quarter of 2021,~~ primarily due to ~~increased~~decreased pretax income. The net effective tax rate for the second quarter of ~~2022 increased to~~2023 was unchanged from the prior year period rate of 22% ~~from 19% for the second quarter of 2021, mostly due to the absence of certain tax benefits related to EOG's exiting of its Canadian operations.~~.

~~-29-~~

Six Months Ended June 30, ~~2022~~2023 vs. Six Months Ended June 30, ~~2021~~2022

Operating Revenues. During the first six months of ~~2022,~~2023, operating revenues increased ~~$3,557~~$227 million, or ~~45%~~2%, to ~~$11,390~~$11,617 million from ~~$7,833~~$11,390 million for the same period of ~~2021.~~2022. Total wellhead revenues for the first six months of ~~2022 increased $5,102~~2023 decreased $3,578 million, or ~~77%~~30%, to ~~$11,762~~$8,184 million from ~~$6,660~~$11,762 million for the same period of ~~2021.~~2022. During the first six months of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$4,197~~$477 million compared to net losses of ~~$794~~$4,197 million for the same period of ~~2021.~~2022. Gathering, processing and marketing revenues for the first six months of ~~2022 increased $1,768~~2023 decreased $783 million, or ~~95%~~22%, to ~~$3,638~~$2,855 million from ~~$1,870~~$3,638 million for the same period of ~~2021.~~2022. Net gains on asset dispositions were ~~$122~~$60 million for the first six months of ~~2022~~2023 compared to net gains of ~~$45~~$122 million for the same period of ~~2021.~~2022.

-30-

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


		Six Months Ended June 30,					Six Months Ended June 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	456.5		437.8		United States	466.6		456.5
Trinidad	Trinidad	0.7		2.0		Trinidad	0.6		0.7
Other International		—		—
Total	Total	457.2		439.8		Total	467.2		457.2
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	$	103.80	$	62.22	United States	$	76.10	$	103.80
Trinidad	Trinidad	90.33		52.57		Trinidad	66.92		90.33
Other International		—		42.36
Composite	Composite	103.78		62.18		Composite	76.09		103.78
Natural Gas Liquids Volumes (MBbld)	Natural Gas Liquids Volumes (MBbld)					Natural Gas Liquids Volumes (MBbld)
United States	United States	196.1		131.5		United States	213.9		196.1
Total	Total	196.1		131.5		Total	213.9		196.1
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	$	41.07	$	28.62	United States	$	23.23	$	41.07
Composite		41.07		28.62
Natural Gas Volumes (MMcfd)	Natural Gas Volumes (MMcfd)					Natural Gas Volumes (MMcfd)
United States	United States	1,287		1,150		United States	1,494		1,287
Trinidad	Trinidad	206		225		Trinidad	160		206
Other International		—		19
Total	Total	1,493		1,394		Total	1,654		1,493
Average Natural Gas Prices ($/Mcf) (1)	Average Natural Gas Prices ($/Mcf) (1)					Average Natural Gas Prices ($/Mcf) (1)
United States	United States	$	6.83	$	4.19	United States	$	2.76	$	6.83
Trinidad	Trinidad	3.39		3.37		Trinidad	3.67		3.39
Other International		—		5.67
Composite	Composite	6.35		4.08		Composite	2.84		6.35
Crude Oil Equivalent Volumes (MBoed)	Crude Oil Equivalent Volumes (MBoed)					Crude Oil Equivalent Volumes (MBoed)
United States	United States	867.1		761.0		United States	929.5		867.1
Trinidad	Trinidad	35.0		39.5		Trinidad	27.2		35.0
Other International		—		3.1
Total	Total	902.1		803.6		Total	956.7		902.1

Total MMBoe	Total MMBoe	163.3		145.4		Total MMBoe	173.2		163.3

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

-31-

Wellhead crude oil and condensate revenues for the first six months of ~~2022 increased $3,638~~2023 decreased $2,154 million, or ~~73%~~25%, to ~~$8,588~~$6,434 million from ~~$4,950~~$8,588 million for the same period of ~~2021~~2022 due to a ~~higher~~lower composite average price ($~~3,439~~2,341 million) ~~and~~, partially offset by an increase of ~~17.4~~10.0 MBbld, or 4%2%, in wellhead crude oil and condensate production ($~~199~~187 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 six months of ~~2022 increased 67%~~2023 decreased 27% to ~~$103.78~~$76.09 per barrel compared to ~~$62.18~~$103.78 per barrel for the same period of ~~2021.~~2022.

NGL revenues for the first six months of ~~2022 increased $777~~2023 decreased $559 million, or ~~114%~~38%, to ~~$1,458~~$899 million from ~~$681~~$1,458 million for the same period of ~~2021~~2022 due to a ~~higher~~lower composite average price ($~~442~~690 million) ~~and~~, partially offset by an increase of ~~64.6~~17.8 MBbld, or ~~49%~~9%, in NGL deliveries ($~~335~~131 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 six months of ~~2022 increased~~2023 decreased 43% to ~~$41.07~~$23.23 per barrel compared to ~~$28.62~~$41.07 per barrel for the same period of ~~2021.~~2022.

Wellhead natural gas revenues for the first six months of ~~2022 increased $687~~2023 decreased $865 million, or ~~67%~~50%, to ~~$1,716~~$851 million from ~~$1,029~~$1,716 million for the same period of ~~2021.~~2022. The ~~increase~~decrease was due to a ~~higher~~lower composite ~~wellhead natural gas~~average price ($~~614~~1,049 million) ~~and~~, partially offset by an increase in natural gas deliveries ($73184 million). Natural gas deliveries for the first six months of ~~2022~~2023 increased 99161 MMcfd, or 7%11%, 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 six months of ~~2022 increased 56%~~2023 decreased 55% to ~~$6.35~~$2.84 per Mcf compared to ~~$4.08~~$6.35 per Mcf for the same period of ~~2021.~~2022.

During the first six months of ~~2022,~~2023, EOG recognized net ~~losses~~gains on the mark-to-market of financial commodity derivative contracts of ~~$4,197~~$477 million compared to net losses of ~~$794~~$4,197 million for the same period of ~~2021.~~2022. During the first six months of ~~2022,~~2023, net cash paid for settlements of financial commodity derivative contracts was $153 million. Net cash paid for settlements of financial commodity derivative contracts was $2,410 million of which $1,328 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 $1,021 million to terminate contracts scheduled to settle after December 31, 2022. Net cash paid for settlements of financial commodity derivative contracts was $223 million for the same period of ~~2021.~~2022.

Gathering, processing and marketing revenues less marketing costs for the first six months of ~~2022 increased $187~~2023 decreased $190 million as compared to the same period of ~~2021~~2022 primarily due to ~~higher~~lower margins on ~~natural gas marketing and~~ crude oil marketing activities.

Operating and Other Expenses. For the first six months of ~~2022,~~2023, operating expenses of ~~$7,941~~$7,075 million were ~~$2,211~~$866 million ~~higher~~lower than the ~~$5,730~~$7,941 million incurred during the same period of ~~2021.~~2022. The following table presents the costs per Boe for the six-month periods ended June 30, ~~2022~~2023 and ~~2021:~~2022:


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Lease and Well	Lease and Well	$	3.93	$	3.71	Lease and Well	$	4.08	$	3.93
Transportation Costs	Transportation Costs	2.89		2.86		Transportation Costs	2.73		2.89
Gathering and Processing Costs	Gathering and Processing Costs	1.81		1.84		Gathering and Processing Costs	1.84		1.81
DD&A -	DD&A -					DD&A -
Oil and Gas Properties	Oil and Gas Properties	10.31		11.96		Oil and Gas Properties	9.13		10.31
Other Property, Plant and Equipment	Other Property, Plant and Equipment	0.46		0.51		Other Property, Plant and Equipment	0.48		0.46
G&A	G&A	1.54		1.58		G&A	1.66		1.54
Interest Expense, Net	Interest Expense, Net	0.59		0.63		Interest Expense, Net	0.44		0.59
Total (1)	Total (1)	$	21.53	$	23.09	Total (1)	$	20.36	$	21.53

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

~~-32-~~

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 six months ended June 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 ~~$642~~$707 million for the first six months of ~~2022~~2023 increased ~~$102~~$65 million from ~~$540~~$642 million for the same prior year period primarily due to increased operating and maintenance costs in the United States ($7546 million) and Trinidad ($5 million) and increased ~~workover expenditures ($24 million), both~~lease and well administrative expenses in the United ~~States.~~States ($15 million). Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

~~Transportation~~Gathering and processing costs ~~of $472~~increased $23 million to $319 million for the first six months of ~~2022 increased $56 million from $416 million for the same prior year period primarily due~~2023 compared to ~~increased transportation costs related to production from the Permian Basin ($38 million) and the Eagle Ford oil play ($12 million).~~

~~Gathering and processing costs of~~ $296 ~~million for the first six months of 2022 increased $29 million from $267~~ million for the same prior year period primarily due to increased gathering and processing fees related to production from the Permian Basin ($3320 million) and increased operating and maintenance expenses ~~($20 million), both~~ related to production from the Permian Basin ($12 million) and the Rocky Mountain area ($7 million), partially offset by decreased gathering and processing fees related to production from the ~~Eagle Ford oil play~~Rocky Mountain area ($1710 million) and decreased ~~gathering and processing fees and~~ operating and maintenance expenses ~~due to the sale of certain legacy natural gas assets in the Rocky Mountain area ($11 million).~~

~~G&A expenses of $252 million for the first six months of 2022 increased $22 million from $230 million for the same prior year period primarily due to increased employee-related costs.~~

~~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~~production 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.~~Eagle Ford play ($6 million).

DD&A expenses for the first six months of ~~2022~~2023 decreased ~~$56~~$94 million to ~~$1,758~~$1,664 million from ~~$1,814~~$1,758 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first six months of ~~2022~~2023 were ~~$57~~$102 million lower than the same prior year period. The decrease primarily reflects decreased unit rates in the United States ($~~272 million) and in Trinidad ($5 million), decreased production associated with the disposition of the China assets in the second quarter of 2021 ($5 million) and decreased production in Trinidad ($5~~222 million), partially offset by increased production in the United States ($~~233~~117 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 ~~costs as a result of increased efficiencies.~~cost per Boe during the year.

~~Exploration costs~~G&A expenses of ~~$80~~$287 million for the first six months of ~~2022~~2023 increased ~~$12~~$35 million from ~~$68~~$252 million for the same prior year period primarily due to increased employee-related costs.

Interest expense, net of $77 million for the first six months of 2023 decreased $19 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 ($10 million) and decreased interest expense on certain royalty payments ($8 million).

Exploration costs of $97 million for the first six months of 2023 increased $17 million from $80 million for the same prior year period due primarily to increased geological and geophysical expenditures ~~($11 million)~~ in the United States.

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


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Proved properties	Proved properties	$	14	$	—	Proved properties	$	3	$	14
Unproved properties	Unproved properties	108		86		Unproved properties	65		108
Other assets	Other assets	23		—		Other assets	—		23
Firm commitment contracts	Firm commitment contracts	1		2		Firm commitment contracts	1		1
Total	Total	$	146	$	88	Total	$	69	$	146

-33-

Taxes other than income for the first six months of ~~2022 increased $408~~2023 decreased $220 million to ~~$862~~$642 million ~~(7.3%~~(7.8% of wellhead revenues) from ~~$454~~$862 million ~~(6.8%~~(7.3% of wellhead revenues) for the same prior year period. The ~~increase~~decrease in taxes other than income was primarily due to ~~increased~~decreased severance/production taxes ($~~344~~227 million) and increased state severance tax refunds ($4 million), partially offset by increased ad valorem/property taxes ($~~57 million) and increased payroll taxes ($6~~16 million), all in the United States.

Other income, net was ~~$26~~$116 million for the first six months of ~~2022~~2023 compared to other ~~expense,~~income, net of $6$26 million for the same prior year period. The change of ~~$32~~$90 million in the first ~~half~~six months of ~~2022~~2023 was primarily due to ~~higher equity income from ammonia plants in Trinidad ($23 million),~~ increased interest income ($6107 million) and ~~a decrease in~~decreased deferred compensation expense ($57 million), partially offset by the absence of equity income due to the sale of EOG's equity interest in ammonia plant investments in Trinidad in the first quarter of 2023 ($28 million).

EOG recognized an income tax provision of $1,005 million for the first six months of 2023 compared to an income tax provision of $751 million for the first six months of 2022, ~~compared to an income tax provision of $421 million for the first six months of 2021,~~ primarily due to increased pretax income. The net effective tax rate for the first six months of ~~2022 increased to~~2023 was unchanged from the prior year period tax rate of 22% ~~from 21% in the first six months of 2021.~~.

Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the six months ended June 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; ~~net cash paid for settlements~~repayment of ~~financial commodity derivative contracts; exploration and development expenditures; net collateral posted for financial commodity derivative contracts;~~maturing debt; purchases of treasury stock; and other property, plant and equipment expenditures. During the first six months of ~~2022,~~2023, EOG's cash balance decreased ~~$2,136~~$1,208 million to ~~$3,073~~$4,764 million from ~~$5,209~~$5,972 million at December 31, ~~2021.~~2022.

Net cash provided by operating activities of ~~$2,876~~$5,532 million for the first six months of ~~2022 decreased $553~~2023 increased $2,656 million compared to the same period of ~~2021~~2022 primarily due to ~~an increase~~a decrease in net cash paid for settlements of financial commodity derivative contracts ($~~2,187~~2,257 million), ~~an increase~~net cash provided by a change in ~~net~~ collateral posted for financial commodity derivative contracts ($~~1,659~~2,090 million), ~~an unfavorable change in~~ net cash ~~paid for income taxes~~provided by working capital and other assets and liabilities in the first six months of 2023 ($~~921~~76 million)~~, an increase in cash operating expenses ($622 million),~~ compared to net cash used in working capital and other assets and liabilities in the first six months of 2022 ($1,164 million) ~~compared to~~and a decrease in net cash ~~used in working capital and other assets and liabilities in the first six months of 2021~~paid for income taxes ($~~514~~941 million), partially offset by ~~an increase~~a decrease in wellhead revenues ($~~5,102~~3,578 million) and ~~an increase~~a decrease in gathering, processing and marketing revenues less marketing costs ($~~187~~190 million).

Net cash used in investing activities of ~~$2,443~~$3,309 million for the first six months of ~~2022~~2023 increased ~~$794~~$866 million compared to the same period of ~~2021~~2022 due to an increase in additions to oil and gas properties ($~~445~~358 million), an increase in additions to other property, plant and equipment ($354 million), a decrease in proceeds from the sale of assets ($110 million) and net cash used in working capital associated with investing activities in the first six months of 2023 ($285 million) compared to net cash used in working capital associated with investing activities in the first six months of 2022 ($211 million) ~~compared to net cash provided~~, partially offset by ~~working capital associated with investing activities in the first six months of 2021 ($145 million), an increase in additions to other property, plant and equipment ($48 million) and an increase~~a decrease in other investing activities ($30 million)~~, partially offset by an increase in proceeds from the sale of assets ($85 million)~~.

Net cash used in financing activities of $3,431 million for the first six months of 2023 included cash dividend payments ($1,547 million), repayments of long-term debt ($1,250 million), purchases of treasury stock ($619 million) and repayment of finance lease liabilities ($16 million). Net cash used in financing activities of $2,569 million for the first six months of 2022 included cash dividend payments ($2,509 million), purchases of treasury stock in connection with stock compensation plans ($58 million) and repayment of finance lease liabilities ($19 million). Net cash used in financing activities of $1,229 million for the first six months of 2021 included repayments of long-term debt ($750 million), cash dividend payments ($458 million) and repayment of finance lease liabilities ($18 million).

-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 ~~$4.3~~$5.8 billion to ~~$4.7~~$6.2 billion, excluding acquisitions, non-cash transactions and exploration costs. The table below sets out components of total expenditures for the six-month periods ended June 30, ~~2022~~2023 and ~~2021~~2022 (in millions):


		Six Months Ended June 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Expenditure Category	Expenditure Category					Expenditure Category
Capital	Capital					Capital
Exploration and Development Drilling(1)	Exploration and Development Drilling(1)	$	1,679	$	1,444	Exploration and Development Drilling(1)	$	2,394	$	1,679
Facilities	Facilities	199		187		Facilities	226		199
Leasehold Acquisitions ~~(1)~~(2)	Leasehold Acquisitions ~~(1)~~(2)	98		104		Leasehold Acquisitions ~~(1)~~(2)	102		98
Property Acquisitions ~~(2)~~(3)	Property Acquisitions ~~(2)~~(3)	356		95		Property Acquisitions ~~(2)~~(3)	10		356
Capitalized Interest	Capitalized Interest	15		15		Capitalized Interest	16		15
Subtotal	Subtotal	2,347		1,845		Subtotal	2,748		2,347
Exploration Costs	Exploration Costs	80		68		Exploration Costs	97		80
Dry Hole Costs	Dry Hole Costs	23		24		Dry Hole Costs	1		23
Exploration and Development Expenditures	Exploration and Development Expenditures	2,450		1,937		Exploration and Development Expenditures	2,846		2,450
Asset Retirement Costs	Asset Retirement Costs	70		48		Asset Retirement Costs	36		70
Total Exploration and Development Expenditures	Total Exploration and Development Expenditures	2,520		1,985		Total Exploration and Development Expenditures	2,882		2,520
Other Property, Plant and Equipment ~~(3)~~(4)	Other Property, Plant and Equipment ~~(3)~~(4)	145		171		Other Property, Plant and Equipment ~~(3)~~(4)	499		145
Total Expenditures	Total Expenditures	$	2,665	$	2,156	Total Expenditures	$	3,381	$	2,665

(1) Exploration and development drilling included $35 million for the six-month period ended June 30, 2023, related to non-cash development drilling.

(2) Leasehold acquisitions included ~~$79~~$59 million and ~~$22~~$79 million for the six-month periods ended June 30, ~~2022~~2023 and ~~2021,~~2022, respectively, related to non-cash property exchanges.

~~(2)~~(3) Property acquisitions included $5$9 million and $3$5 million for the six-month periods ended June 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 six-month period ended June 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 ~~$2,450~~$2,846 million for the first six months of ~~2022~~2023 were ~~$513~~$396 million higher than the same period of ~~2021~~2022 primarily due to ~~increased property acquisitions ($261 million),~~ increased exploration and development drilling expenditures in the United States ($~~258~~695 million) and increased facilities expenditures ($1227 million), partially offset by decreased ~~exploration~~property acquisitions ($346 million). Exploration and development expenditures for the first six months of 2023 of $2,846 million consisted of $2,545 million in development drilling ~~expenditures~~and facilities, $275 million in ~~Trinidad ($18 million)~~exploration, $16 million in capitalized interest and ~~Other International ($4 million) and decreased leasehold acquisitions ($6 million).~~$10 million in property acquisitions. Exploration and development expenditures for the first six months of 2022 of $2,450 million consisted of $1,845 million in development drilling and facilities, $356 million in property acquisitions, $234 million in exploration and $15 million in capitalized interest. Exploration and development expenditures for the first six months of 2021 of $1,937 million consisted of $1,630 million in development drilling and facilities, $197 million in exploration, $95 million in property acquisitions and $15 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.

-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 June 30, ~~2022,~~2023, as a net liability of ~~$123~~$296 million.

As discussed in "Operating Revenues and Other," the net cash paid for settlements of financial commodity derivative contracts during the second quarter and first six months of ~~2022~~2023 was ~~$2,114~~$30 million and ~~$2,410~~$153 million, respectively, of which $1,328 million during both the second quarter and first six months of 2022 was related to the early termination of certain contracts; see the below summary tables for further discussion.respectively.

Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the period from January 1, ~~2022~~2023 to July ~~29, 2022~~31, 2023 (closed) and outstanding as of July ~~29, 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 - August 2023 (closed)

NYMEX Henry Hub

300

3.36

September - 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

-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 2022 (closed) NYMEX WTI 140 65.59 — —
August - September 2022 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 - February 2023 (closed) (1)
NYMEX WTI 7 69.51 — —
January - February 2023 NYMEX WTI 143 67.84 6 102.26
March 2023 (closed) (1)
NYMEX WTI 37 67.35 — —
March 2023 NYMEX WTI 113 68.11 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 - August 2022 (closed)
NYMEX WTI Roll Differential (1)
125 $ 0.15
September - 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.~~

~~-37-~~

Natural Gas Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price ($/MMBtu)
January - August 2022 (closed) NYMEX Henry Hub 725 $ 3.57
September 2022 NYMEX Henry Hub 725 3.57
October - December 2022 (closed) (1)
NYMEX Henry Hub 425 3.05
October - 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 - July 2022 (closed)

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

210

(0.01)

August - December 2022

NYMEX Henry Hub HSC Differential (1)

210

(0.01)

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

(0.01)

January - July 2023 (closed)

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

135

0.01

August - 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 ~~$1,529 million of~~no collateral posted and no collateral held at August ~~3, 2022. EOG expects this collateral to be applied to the settlement of financial commodity derivative contracts if market prices remain above contract prices.~~2, 2023. The amount of posted collateral will increase or decrease based on fluctuations in forward NYMEX WTI and Henry Hub prices.

-37-

~~-38-~~

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;

~~-39-~~-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.

-40-

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" 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(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 June 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)
April 1, 2022 - April 30, 2022 23,045 $ 123.44 — $ 5,000,000,000
May 1, 2022 - May 31, 2022 53,666 131.72 — $ 5,000,000,000
June 1, 2022 - June 30, 2022 35,276 139.52 — $ 5,000,000,000
Total 111,987 132.47 —��


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)


April 1, 2023 - April 30, 2023	8,628	$	120.58	$	—	$	4,689,743,029
May 1, 2023 - May 31, 2023	1,848,250	108.23		199,538,361		$	4,490,204,668
June 1, 2023 - June 30, 2023	928,159	108.80		100,461,600		$	4,389,743,068
Total	2,785,037	108.46		299,999,961

(1)~~The 111,987 total~~Includes 2,767,398 shares ~~for~~repurchased during the quarter ended June 30, ~~2022, consist solely~~2023, at an average price of $108.41 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 17,639 total shares that were withheld by or returned to EOG during the quarter ended June 30, 2023, at an average price of $116.53 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 5,709,234 shares at a total cost of $610,256,932 (inclusive of commissions and transaction fees) under the November 2021 Authorization and (ii) an additional $4,389,743,068 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

Trading Plans/Arrangements. During the quarter ended June 30, 2023, no director or Section 16 officer of EOG adopted or terminated any Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (in each case, as defined in Item 408(a) of Regulation S-K).

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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	-	Revolving Credit Agreement, dated as of June 7, 2023, among EOG, JPMorgan Chase Bank, N.A., as Administrative Agent, the financial institutions as bank parties thereto, and the other parties thereto (incorporated by reference to Exhibit 10.1 to EOG's Current Report on Form 8-K, filed June 12, 2023 (SEC File No. 001-09743).

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 Six Months ~~ended~~Ended June 30, ~~2022~~2023 and ~~2021,~~2022, (ii) the Condensed Consolidated Balance Sheets - June 30, ~~2022~~2023 and December 31, ~~2021,~~2022, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three Months and Six Months Ended June 30, ~~2022~~2023 and ~~2021,~~2022, (iv) the Condensed Consolidated Statements of Cash Flows - Six Months Ended June 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:	August ~~4, 2022~~3, 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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