UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549



FORM			10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~March 31,~~September 30, 2022

☐ 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	~~585,713,473~~587,389,496	(as of ~~April 28,~~October 27, 2022)

EOG RESOURCES, INC.

TABLE OF CONTENTS


PART I.	FINANCIAL INFORMATION		Page No.

	ITEM 1.	Financial Statements (Unaudited)

		Condensed Consolidated Statements of Income and Comprehensive Income - Three Months and Nine Months Ended ~~March 31,~~September 30, 2022 and 2021	3

		Condensed Consolidated Balance Sheets - ~~March 31,~~September 30, 2022 and December 31, 2021	4

		Condensed Consolidated Statements of Stockholders' Equity - Three Months and Nine Months Ended ~~March 31,~~September 30, 2022 and 2021	5

		Condensed Consolidated Statements of Cash Flows - ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022 and 2021	67

		Notes to Condensed Consolidated Financial Statements	78

	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	2123

	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	3442

	ITEM 4.	Controls and Procedures	3442

PART II.	OTHER INFORMATION

	ITEM 1.	Legal Proceedings	3543

	ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3543

	ITEM 4.	Mine Safety Disclosures	3543

	ITEM 5.	Other Information	44

	ITEM 6.	Exhibits	3645

SIGNATURES			3847

-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 March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021				2022		2021		2022		2021
Operating Revenues and Other	Operating Revenues and Other						Operating Revenues and Other
Crude Oil and Condensate	Crude Oil and Condensate	$	3,889	$	2,251		Crude Oil and Condensate	$	4,109	$	2,929	$	12,697	$	7,879
Natural Gas Liquids	Natural Gas Liquids	681		314			Natural Gas Liquids	693		548		2,151		1,229
Natural Gas	Natural Gas	716		625			Natural Gas	1,235		568		2,951		1,597
Losses on Mark-to-Market Financial Commodity Derivative Contracts	Losses on Mark-to-Market Financial Commodity Derivative Contracts	(2,820)		(367)			Losses on Mark-to-Market Financial Commodity Derivative Contracts	(18)		(494)		(4,215)		(1,288)
Gathering, Processing and Marketing	Gathering, Processing and Marketing	1,469		848			Gathering, Processing and Marketing	1,561		1,186		5,199		3,056
Gains (Losses) on Asset Dispositions, Net	Gains (Losses) on Asset Dispositions, Net	25		(6)			Gains (Losses) on Asset Dispositions, Net	(21)		1		101		46
Other, Net	Other, Net	23		29			Other, Net	34		27		99		79
Total	Total	3,983		3,694			Total	7,593		4,765		18,983		12,598
Operating Expenses	Operating Expenses						Operating Expenses
Lease and Well	Lease and Well	318		270			Lease and Well	335		270		977		810
Transportation Costs	Transportation Costs	228		202			Transportation Costs	257		219		729		635
Gathering and Processing Costs	Gathering and Processing Costs	144		139			Gathering and Processing Costs	167		145		463		412
Exploration Costs	Exploration Costs	45		33			Exploration Costs	35		44		115		112
Dry Hole Costs	Dry Hole Costs	3		11			Dry Hole Costs	18		4		41		28
Impairments	Impairments	55		44			Impairments	94		82		240		170
Marketing Costs	Marketing Costs	1,283		838			Marketing Costs	1,621		1,184		5,031		3,013
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	847		900			Depreciation, Depletion and Amortization	906		927		2,664		2,741
General and Administrative	General and Administrative	124		110			General and Administrative	162		142		414		372
Taxes Other Than Income	Taxes Other Than Income	390		215			Taxes Other Than Income	334		277		1,196		731
Total	Total	3,437		2,762			Total	3,929		3,294		11,870		9,024
Operating Income	Operating Income	546		932			Operating Income	3,664		1,471		7,113		3,574
Other Expense, Net		(1)		(4)
Other Income, Net							Other Income, Net	40		6		66		—
Income Before Interest Expense and Income Taxes	Income Before Interest Expense and Income Taxes	545		928			Income Before Interest Expense and Income Taxes	3,704		1,477		7,179		3,574
Interest Expense, Net	Interest Expense, Net	48		47			Interest Expense, Net	41		48		137		140
Income Before Income Taxes	Income Before Income Taxes	497		881			Income Before Income Taxes	3,663		1,429		7,042		3,434
Income Tax Provision	Income Tax Provision	107		204			Income Tax Provision	809		334		1,560		755
Net Income	Net Income	$	390	$	677		Net Income	$	2,854	$	1,095	$	5,482	$	2,679
Net Income Per Share	Net Income Per Share						Net Income Per Share
Basic	Basic	$	0.67	$	1.17		Basic	$	4.90	$	1.88	$	9.40	$	4.62
Diluted	Diluted	$	0.67	$	1.16		Diluted	$	4.86	$	1.88	$	9.34	$	4.59
Average Number of Common Shares	Average Number of Common Shares						Average Number of Common Shares
Basic	Basic	582		580			Basic	583		581		583		580
Diluted	Diluted	586		583			Diluted	587		584		587		584
Comprehensive Income	Comprehensive Income						Comprehensive Income
Net Income	Net Income	$	390	$	677		Net Income	$	2,854	$	1,095	$	5,482	$	2,679
Other Comprehensive Loss
Other Comprehensive Income (Loss)							Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	Foreign Currency Translation Adjustments	(1)		(2)			Foreign Currency Translation Adjustments	5		2		6		(1)
Other, Net of Tax	Other, Net of Tax	—		—			Other, Net of Tax	1		—		—		—
Other Comprehensive Loss		(1)		(2)
Other Comprehensive Income (Loss)							Other Comprehensive Income (Loss)	6		2		6		(1)
Comprehensive Income	Comprehensive Income	$	389	$	675		Comprehensive Income	$	2,860	$	1,097	$	5,488	$	2,678

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)


		March 31, 2022		December 31, 2021			September 30, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and Cash Equivalents	Cash and Cash Equivalents	$	4,009	$	5,209	Cash and Cash Equivalents	$	5,272	$	5,209
Accounts Receivable, Net	Accounts Receivable, Net	3,213		2,335		Accounts Receivable, Net	3,343		2,335
Inventories	Inventories	586		584		Inventories	872		584
Income Taxes Receivable						Income Taxes Receivable	93		—
Other	Other	671		456		Other	621		456
Total	Total	8,479		8,584		Total	10,201		8,584
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)	65,408		67,644		Oil and Gas Properties (Successful Efforts Method)	67,065		67,644
Other Property, Plant and Equipment	Other Property, Plant and Equipment	4,801		4,753		Other Property, Plant and Equipment	4,659		4,753
Total Property, Plant and Equipment	Total Property, Plant and Equipment	70,209		72,397		Total Property, Plant and Equipment	71,724		72,397
Less: Accumulated Depreciation, Depletion and Amortization	Less: Accumulated Depreciation, Depletion and Amortization	(41,747)		(43,971)		Less: Accumulated Depreciation, Depletion and Amortization	(42,623)		(43,971)
Total Property, Plant and Equipment, Net	Total Property, Plant and Equipment, Net	28,462		28,426		Total Property, Plant and Equipment, Net	29,101		28,426
Deferred Income Taxes	Deferred Income Taxes	13		11		Deferred Income Taxes	18		11
Other Assets	Other Assets	1,143		1,215		Other Assets	1,167		1,215
Total Assets	Total Assets	$	38,097	$	38,236	Total Assets	$	40,487	$	38,236
LIABILITIES AND STOCKHOLDERS' EQUITY	LIABILITIES AND STOCKHOLDERS' EQUITY					LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts Payable	Accounts Payable	$	2,660	$	2,242	Accounts Payable	$	2,718	$	2,242
Accrued Taxes Payable	Accrued Taxes Payable	1,130		518		Accrued Taxes Payable	542		518
Dividends Payable	Dividends Payable	436		436		Dividends Payable	437		436
Liabilities from Price Risk Management Activities	Liabilities from Price Risk Management Activities	260		269		Liabilities from Price Risk Management Activities	243		269
Current Portion of Long-Term Debt	Current Portion of Long-Term Debt	1,283		37		Current Portion of Long-Term Debt	1,282		37
Current Portion of Operating Lease Liabilities	Current Portion of Operating Lease Liabilities	223		240		Current Portion of Operating Lease Liabilities	235		240
Other	Other	272		300		Other	289		300
Total	Total	6,264		4,042		Total	5,746		4,042

Long-Term Debt	Long-Term Debt	3,816		5,072		Long-Term Debt	3,802		5,072
Other Liabilities	Other Liabilities	2,191		2,193		Other Liabilities	2,573		2,193
Deferred Income Taxes	Deferred Income Taxes	4,286		4,749		Deferred Income Taxes	4,517		4,749
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 585,944,344 Shares Issued at March 31, 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 587,891,710 Shares Issued at September 30, 2022 and 585,521,512 Shares Issued at December 31, 2021						Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 587,891,710 Shares Issued at September 30, 2022 and 585,521,512 Shares Issued at December 31, 2021	206		206
Additional Paid in Capital	Additional Paid in Capital	6,095		6,087		Additional Paid in Capital	6,155		6,087
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss	(13)		(12)		Accumulated Other Comprehensive Loss	(6)		(12)
Retained Earnings	Retained Earnings	15,283		15,919		Retained Earnings	17,563		15,919
Common Stock Held in Treasury, 290,472 Shares at March 31, 2022 and 257,268 Shares at December 31, 2021		(31)		(20)
Common Stock Held in Treasury, 646,861 Shares at September 30, 2022 and 257,268 Shares at December 31, 2021						Common Stock Held in Treasury, 646,861 Shares at September 30, 2022 and 257,268 Shares at December 31, 2021	(69)		(20)
Total Stockholders' Equity	Total Stockholders' Equity	21,540		22,180		Total Stockholders' Equity	23,849		22,180
Total Liabilities and Stockholders' Equity	Total Liabilities and Stockholders' Equity	$	38,097	$	38,236	Total Liabilities and Stockholders' Equity	$	40,487	$	38,236

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 December 31, 2021		$	206	$	6,087	$	(12)	$	15,919	$	(20)	$	22,180
Balance at June 30, 2022														Balance at June 30, 2022	$	206	$	6,128	$	(12)	$	16,028	$	(38)	$	22,312
Net Income	Net Income	—		—		—		390		—		390		Net Income	—		—		—		2,854		—		2,854
Common Stock Dividends Declared, $1.75 Per Share		—		—		—		(1,026)		—		(1,026)
Other Comprehensive Loss		—		—		(1)		—		—		(1)
Common Stock Dividends Declared, $2.25 Per Share														Common Stock Dividends Declared, $2.25 Per Share	—		—		—		(1,319)		—		(1,319)
Other Comprehensive Income														Other Comprehensive Income	—		—		6		—		—		6
Common Stock Issued Under Stock Plans	Common Stock Issued Under Stock Plans	—		—		—		—		—		—		Common Stock Issued Under Stock Plans	—		—		—		—		—		—
Change in Treasury Stock - Stock Compensation Plans, Net	Change in Treasury Stock - Stock Compensation Plans, Net	—		(24)		—		—		(14)		(38)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(5)		—		—		(33)		(38)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(3)		—		—		3		—		Restricted Stock and Restricted Stock Units, Net	—		(2)		—		—		2		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		35		—		—		—		35		Stock-Based Compensation Expenses	—		34		—		—		—		34
Treasury Stock Issued as Compensation	Treasury Stock Issued as Compensation	—		—		—		—		—		—		Treasury Stock Issued as Compensation	—		—		—		—		—		—
Balance at March 31, 2022		$	206	$	6,095	$	(13)	$	15,283	$	(31)	$	21,540
Balance at September 30, 2022														Balance at September 30, 2022	$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849


		Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity			Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at December 31, 2020		$	206	$	5,945	$	(12)	$	14,170	$	(7)	$	20,302
Balance at June 30, 2021														Balance at June 30, 2021	$	206	$	6,017	$	(15)	$	14,689	$	(16)	$	20,881
Net Income	Net Income	—		—		—		677		—		677		Net Income	—		—		—		1,095		—		1,095
Common Stock Dividends Declared, $0.4125 Per Share	Common Stock Dividends Declared, $0.4125 Per Share	—		—		—		(241)		—		(241)		Common Stock Dividends Declared, $0.4125 Per Share	—		—		—		(242)		—		(242)
Other Comprehensive Loss		—		—		(2)		—		—		(2)
Other Comprehensive Income														Other Comprehensive Income	—		—		2		—		—		2
Common Stock Issued Under Stock Plans														Common Stock Issued Under Stock Plans	—		—		—		—		—		—
Change in Treasury Stock - Stock Compensation Plans, Net	Change in Treasury Stock - Stock Compensation Plans, Net	—		—		—		—		(9)		(9)		Change in Treasury Stock - Stock Compensation Plans, Net	—		(5)		—		—		(17)		(22)
Restricted Stock and Restricted Stock Units, Net	Restricted Stock and Restricted Stock Units, Net	—		(1)		—		—		1		—		Restricted Stock and Restricted Stock Units, Net	—		(5)		—		—		5		—
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	—		35		—		—		—		35		Stock-Based Compensation Expenses	—		51		—		—		—		51
Treasury Stock Issued as Compensation	Treasury Stock Issued as Compensation	—		—		—		—		—		—		Treasury Stock Issued as Compensation	—		—		—		—		—		—
Balance at March 31, 2021		$	206	$	5,979	$	(14)	$	14,606	$	(15)	$	20,762
Balance at September 30, 2021														Balance at September 30, 2021	$	206	$	6,058	$	(13)	$	15,542	$	(28)	$	21,765

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

-5-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Millions, Except Per Share Data)

(Unaudited)


	Common Stock		Additional Paid In Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Common Stock Held In Treasury		Total Stockholders' Equity
Balance at December 31, 2021	$	206	$	6,087	$	(12)	$	15,919	$	(20)	$	22,180
Net Income	—		—		—		5,482		—		5,482
Common Stock Dividends Declared, $6.55 Per Share	—		—		—		(3,838)		—		(3,838)
Other Comprehensive Income	—		—		6		—		—		6
Common Stock Issued Under Stock Plans	—		13		—		—		—		13
Change in Treasury Stock - Stock Compensation Plans, Net	—		(40)		—		—		(53)		(93)
Restricted Stock and Restricted Stock Units, Net	—		(4)		—		—		4		—
Stock-Based Compensation Expenses	—		99		—		—		—		99
Treasury Stock Issued as Compensation	—		—		—		—		—		—
Balance at September 30, 2022	$	206	$	6,155	$	(6)	$	17,563	$	(69)	$	23,849


	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
Net Income	—		—		—		2,679		—		2,679
Common Stock Dividends Declared, $2.2375 Per Share	—		—		—		(1,307)		—		(1,307)
Other Comprehensive Loss	—		—		(1)		—		—		(1)
Common Stock Issued Under Stock Plans	—		9		—		—		—		9
Change in Treasury Stock - Stock Compensation Plans, Net	—		(7)		—		—		(27)		(34)
Restricted Stock and Restricted Stock Units, Net	—		(6)		—		—		6		—
Stock-Based Compensation Expenses	—		117		—		—		—		117
Treasury Stock Issued as Compensation	—		—		—		—		—		—
Balance at September 30, 2021	$	206	$	6,058	$	(13)	$	15,542	$	(28)	$	21,765

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)


		Three Months Ended March 31,					Nine Months Ended September 30,
		2022		2021			2022		2021
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	$	390	$	677	Net Income	$	5,482	$	2,679
Items Not Requiring (Providing) Cash	Items Not Requiring (Providing) Cash					Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	Depreciation, Depletion and Amortization	847		900		Depreciation, Depletion and Amortization	2,664		2,741
Impairments	Impairments	55		44		Impairments	240		170
Stock-Based Compensation Expenses	Stock-Based Compensation Expenses	35		35		Stock-Based Compensation Expenses	99		117
Deferred Income Taxes	Deferred Income Taxes	(465)		(36)		Deferred Income Taxes	(240)		(244)
(Gains) Losses on Asset Dispositions, Net		(25)		6
Gains on Asset Dispositions, Net						Gains on Asset Dispositions, Net	(101)		(46)
Other, Net	Other, Net	6		7		Other, Net	(15)		15
Dry Hole Costs	Dry Hole Costs	3		11		Dry Hole Costs	41		28
Mark-to-Market Financial Commodity Derivative Contracts	Mark-to-Market Financial Commodity Derivative Contracts					Mark-to-Market Financial Commodity Derivative Contracts
Total Losses	Total Losses	2,820		367		Total Losses	4,215		1,288
Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(296)		(30)		Net Cash Payments for Settlements of Financial Commodity Derivative Contracts	(3,257)		(516)
Other, Net	Other, Net	2		1		Other, Net	33		8
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	(878)		(308)		Accounts Receivable	(1,008)		(639)
Inventories	Inventories	(14)		64		Inventories	(311)		95
Accounts Payable	Accounts Payable	130		172		Accounts Payable	301		115
Accrued Taxes Payable	Accrued Taxes Payable	613		243		Accrued Taxes Payable	24		286
Other Assets	Other Assets	(213)		(103)		Other Assets	(271)		(55)
Other Liabilities	Other Liabilities	(2,250)		(89)		Other Liabilities	(548)		(317)
Changes in Components of Working Capital Associated with Investing Activities	Changes in Components of Working Capital Associated with Investing Activities	68		(91)		Changes in Components of Working Capital Associated with Investing Activities	301		(100)
Net Cash Provided by Operating Activities	Net Cash Provided by Operating Activities	828		1,870		Net Cash Provided by Operating Activities	7,649		5,625
Investing Cash Flows	Investing Cash Flows					Investing Cash Flows
Additions to Oil and Gas Properties	Additions to Oil and Gas Properties	(939)		(875)		Additions to Oil and Gas Properties	(3,390)		(2,689)
Additions to Other Property, Plant and Equipment	Additions to Other Property, Plant and Equipment	(70)		(42)		Additions to Other Property, Plant and Equipment	(248)		(147)
Proceeds from Sales of Assets	Proceeds from Sales of Assets	121		5		Proceeds from Sales of Assets	310		154
Other Investing Activities						Other Investing Activities	(30)		—
Changes in Components of Working Capital Associated with Investing Activities	Changes in Components of Working Capital Associated with Investing Activities	(68)		91		Changes in Components of Working Capital Associated with Investing Activities	(301)		100
Net Cash Used in Investing Activities	Net Cash Used in Investing Activities	(956)		(821)		Net Cash Used in Investing Activities	(3,659)		(2,582)
Financing Cash Flows	Financing Cash Flows					Financing Cash Flows
Long-Term Debt Repayments	Long-Term Debt Repayments	—		(750)		Long-Term Debt Repayments	—		(750)
Dividends Paid	Dividends Paid	(1,023)		(219)		Dividends Paid	(3,821)		(1,278)
Treasury Stock Purchased	Treasury Stock Purchased	(43)		(10)		Treasury Stock Purchased	(95)		(33)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	4		—		Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	17		9
Repayment of Finance Lease Liabilities	Repayment of Finance Lease Liabilities	(10)		(9)		Repayment of Finance Lease Liabilities	(27)		(27)
Net Cash Used in Financing Activities	Net Cash Used in Financing Activities	(1,072)		(988)		Net Cash Used in Financing Activities	(3,926)		(2,079)
Effect of Exchange Rate Changes on Cash	Effect of Exchange Rate Changes on Cash	—		(2)		Effect of Exchange Rate Changes on Cash	(1)		—
Increase (Decrease) in Cash and Cash Equivalents		(1,200)		59
Increase in Cash and Cash Equivalents						Increase in Cash and Cash Equivalents	63		964
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	5,209		3,329
Cash and Cash Equivalents at End of Period	Cash and Cash Equivalents at End of Period	$	4,009	$	3,388	Cash and Cash Equivalents at End of Period	$	5,272	$	4,293

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

~~-6-~~-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, filed on February 24, 2022 (EOG's 2021 Annual Report).

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three and nine months ended ~~March 31,~~September 30, 2022, are not necessarily indicative of the results to be expected for the full year.

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

~~-7-~~-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 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 March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021				2022		2021		2022		2021
Lease and Well	Lease and Well	$	13	$	14		Lease and Well	$	6	$	11	$	29	$	36
Gathering and Processing Costs	Gathering and Processing Costs	1		—			Gathering and Processing Costs	1		1		3		2
Exploration Costs	Exploration Costs	5		6			Exploration Costs	—		4		10		15
General and Administrative	General and Administrative	16		15			General and Administrative	27		35		57		64
Total	Total	$	35	$	35		Total	$	34	$	51	$	99	$	117

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

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 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, 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 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 ~~March 31,~~September 30, 2022, approximately 1816 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$11 million and ~~$10~~$20 million during the three months ended ~~March 31,~~September 30, 2022 and 2021, respectively, and $28 million and $39 million during the nine months ended September 30, 2022 and 2021, respectively.

Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 are as follows:


		Stock Options/SARs						ESPP							Stock Options/SARs						ESPP
		Three Months Ended March 31,						Three Months Ended March 31,							Nine Months Ended September 30,						Nine Months Ended September 30,
		2022			2021			2022			2021				2022			2021			2022			2021
Weighted Average Fair Value of Grants	Weighted Average Fair Value of Grants	$	28.30		$	17.03		$	23.07		$	14.69		Weighted Average Fair Value of Grants	$	28.30		$	24.92		$	26.71		$	18.15
Expected Volatility	Expected Volatility	42.20		%	47.18		%	39.72		%	54.99		%	Expected Volatility	42.20		%	42.24		%	43.08		%	51.23		%
Risk-Free Interest Rate	Risk-Free Interest Rate	0.89		%	0.28		%	0.22		%	0.09		%	Risk-Free Interest Rate	0.89		%	0.50		%	1.33		%	0.07		%
Dividend Yield	Dividend Yield	3.28		%	3.25		%	3.32		%	3.41		%	Dividend Yield	3.28		%	2.25		%	2.88		%	2.88		%
Expected Life	Expected Life	5.3 years			5.2 years			0.5 years			0.5 years			Expected Life	5.3 years			5.2 years			0.5 years			0.5 years

~~-8-~~-9-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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

The following table sets forth stock option and SAR transactions for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (stock options and SARs in thousands):


		Three Months Ended March 31, 2022			Three Months Ended March 31, 2021				Nine Months Ended September 30, 2022			Nine Months Ended September 30, 2021
		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	9,969	$	84.37	10,186	$	84.08
Granted	Granted	2	97.64		7	53.98		Granted	2	97.64		1,976	81.66
Exercised (1)	Exercised (1)	(2,324)	84.63		(26)	63.25		Exercised (1)	(4,282)	91.63		(448)	64.18
Forfeited	Forfeited	(81)	85.86		(103)	89.21		Forfeited	(192)	84.26		(984)	98.64
Outstanding at March 31 (2)		7,566	$	84.28	10,064	$	84.06
Outstanding at September 30 (2)								Outstanding at September 30 (2)	5,497	$	78.73	10,730	$	83.13
Vested or Expected to Vest (3)	Vested or Expected to Vest (3)	7,256	$	85.05	9,749	$	84.74	Vested or Expected to Vest (3)	5,344	$	79.05	10,407	$	83.65
Exercisable at March 31 (4)		3,886	$	101.26	6,288	$	96.47
Exercisable at September 30 (4)								Exercisable at September 30 (4)	3,686	$	84.18	6,906	$	92.39

(1)The total intrinsic value of stock options/SARs exercised during the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021 was ~~$62~~$122 million and ~~$0.2~~$8 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 ~~March 31,~~September 30, 2022 and 2021 was ~~$277~~$194 million and ~~$71~~$95 million, respectively. At ~~March 31,~~both September 30, 2022 and 2021, the weighted average remaining contractual life was 4.3 ~~years and 4.0 years, respectively.~~years.

(3)The total intrinsic value of stock options/SARs vested or expected to vest at ~~March 31,~~September 30, 2022 and 2021 was ~~$260~~$187 million and ~~$66~~$90 million, respectively. At ~~March 31,~~both September 30, 2022 and 2021, the weighted average remaining contractual life was 4.3 ~~years and 4.0 years, respectively.~~years.

(4)The total intrinsic value of stock options/SARs exercisable at ~~March 31,~~September 30, 2022 and 2021 was ~~$82~~$114 million and $3$38 million, respectively. At ~~March 31,~~September 30, 2022 and 2021, the weighted average remaining contractual life was ~~2.9~~3.7 years and ~~3.0~~3.2 years, respectively.

At ~~March 31,~~September 30, 2022, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled ~~$54~~$38 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.9~~1.7 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 ~~$25~~$18 million and ~~$24~~$20 million for the three months ended ~~March 31,~~September 30, 2022 and ~~2021.~~2021, respectively, and $63 million and $65 million for the nine months ended September 30, 2022 and 2021, respectively.

~~-9-~~-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 ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (shares and units in thousands):


		Three Months Ended March 31, 2022			Three Months Ended March 31, 2021				Nine Months Ended September 30, 2022			Nine Months Ended September 30, 2021
		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	4,680	$	69.37	4,742	$	74.97
Granted	Granted	14	110.66		12	60.27		Granted	1,623	113.03		1,409	81.44
Released (1)	Released (1)	(699)	93.37		(430)	90.27		Released (1)	(1,953)	82.05		(1,321)	101.63
Forfeited	Forfeited	(51)	66.77		(25)	71.16		Forfeited	(130)	65.44		(65)	68.49
Outstanding at March 31 (2)		3,944	$	65.30	4,299	$	73.42
Outstanding at September 30 (2)								Outstanding at September 30 (2)	4,220	$	80.41	4,765	$	69.58

(1)The total intrinsic value of restricted stock and restricted stock units released during the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021 was ~~$81~~$215 million and ~~$31~~$104 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 ~~March 31,~~September 30, 2022 and 2021 was ~~$470~~$472 million and ~~$312~~$383 million, respectively.

At ~~March 31,~~September 30, 2022, unrecognized compensation expense related to restricted stock and restricted stock units totaled ~~$172~~$313 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.5~~2.0 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 EOGs 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$5 million and $1$11 million for the three months ended ~~March 31,~~September 30, 2022 and 2021, respectively, and $8 million and $13 million for the nine months ended September 30, 2022 and 2021, respectively.

~~-10-~~-11-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The following table sets forth the Performance Unit transactions for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (units in thousands):


		Three Months Ended March 31, 2022				Three Months Ended March 31, 2021				Nine Months Ended September 30, 2022				Nine Months Ended September 30, 2021
		Number of Units		Weighted Average Grant Date Fair Value		Number of Units	Weighted Average Grant Date Fair Value			Number of Units		Weighted Average Grant Date Fair Value		Number of Units	Weighted Average Grant Date Fair Value
Outstanding at January 1	Outstanding at January 1	679		$	84.97	613	$	88.38	Outstanding at January 1	679		$	84.97	613	$	88.38
Granted	Granted	—		—		8	49.86		Granted	122		126.55		222	90.94
Granted for Performance Multiple (1)	Granted for Performance Multiple (1)	—		—		19	96.29		Granted for Performance Multiple (1)	—		—		19	113.81
Released (2)	Released (2)	(57)		136.74		(98)	96.29		Released (2)	(57)		136.74		(175)	113.06
Forfeited for Performance Multiple (3)	Forfeited for Performance Multiple (3)	(56)		136.74		—	—		Forfeited for Performance Multiple (3)	(56)		136.74		—	—
Outstanding at March 31 (4)		566	(5)	$	74.60	542	$	76.18
Outstanding at September 30 (4)									Outstanding at September 30 (4)	688	(5)	$	83.82	679	$	83.59

(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 million and $6$13 million for the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Units are released.

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

(4)The total intrinsic value of Performance Units outstanding at ~~March 31,~~September 30, 2022 and 2021 was approximately ~~$67~~$77 million and ~~$39~~$55 million, respectively.

(5)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~~1,376 Performance Units could be outstanding.

At ~~March 31,~~September 30, 2022, unrecognized compensation expense related to Performance Units totaled ~~$11~~$20 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~1.9~~1.8 years.

3. Net Income Per Share

The following table sets forth the computation of Net Income Per Share for the three-month and nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (in millions, except per share data):


		Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021				2022		2021		2022		2021
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	$	390	$	677		Net Income	$	2,854	$	1,095	$	5,482	$	2,679
Denominator for Basic Earnings Per Share -	Denominator for Basic Earnings Per Share -						Denominator for Basic Earnings Per Share -
Weighted Average Shares	Weighted Average Shares	582		580			Weighted Average Shares	583		581		583		580
Potential Dilutive Common Shares -	Potential Dilutive Common Shares -						Potential Dilutive Common Shares -
Stock Options/SARs/ESPP	Stock Options/SARs/ESPP	1		1			Stock Options/SARs/ESPP	1		1		2		1
Restricted Stock/Units and Performance Units	Restricted Stock/Units and Performance Units	3		2			Restricted Stock/Units and Performance Units	3		2		2		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	586		583			Adjusted Diluted Weighted Average Shares	587		584		587		584
Net Income Per Share	Net Income Per Share						Net Income Per Share
Basic	Basic	$	0.67	$	1.17		Basic	$	4.90	$	1.88	$	9.40	$	4.62
Diluted	Diluted	$	0.67	$	1.16		Diluted	$	4.86	$	1.88	$	9.34	$	4.59

~~-11-~~-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 21 million and 87 million for the three-month periods ended ~~March 31,~~September 30, 2022 and 2021, respectively, and were 1 million and 7 million shares for the nine-month periods ended September 30, 2022 and 2021, respectively.

4. Supplemental Cash Flow Information

Net cash paid for interest and income taxes was as follows for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (in millions):


		Three Months Ended March 31,					Nine Months Ended September 30,
		2022		2021			2022		2021
Interest (1)	Interest (1)	$	32	$	49	Interest (1)	$	123	$	134
Income Taxes, Net of Refunds Received	Income Taxes, Net of Refunds Received	$	46	$	20	Income Taxes, Net of Refunds Received	$	2,059	$	775

(1)Net of capitalized interest of $8$26 million and $24 million for ~~both~~ the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and ~~2021.~~2021, respectively.

EOG's accrued capital expenditures at ~~March 31,~~September 30, 2022 and 2021 were ~~$528~~$575 million and ~~$436~~$405 million, respectively.

Non-cash investing activities for the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021, included additions of ~~$63~~$113 million and ~~$25~~$41 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the ~~three~~nine months ended ~~March 31,~~September 30, 2021, also included additions of $74 million to EOG's other property, plant and equipment made in connection with finance lease transactions for storage facilities.

Operating activities for the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021, included the net use of cash of ~~$2,275~~$546 million and $308 million, respectively, related to collateral posted for financial commodity derivative contracts. For related discussion, see Note 12. This amount is 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.

~~-12-~~-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 nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (in millions):


		Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021				2022		2021		2022		2021
Operating Revenues and Other	Operating Revenues and Other						Operating Revenues and Other
United States	United States	$	3,914	$	3,606		United States	$	7,481	$	4,692	$	18,733	$	12,293
Trinidad	Trinidad	69		76			Trinidad	111		72		249		229
Other International (1)	Other International (1)	—		12			Other International (1)	1		1		1		76
Total	Total	$	3,983	$	3,694		Total	$	7,593	$	4,765	$	18,983	$	12,598
Operating Income
Operating Income (Loss)							Operating Income (Loss)
United States	United States	$	519	$	890		United States	$	3,606	$	1,455	$	7,010	$	3,422
Trinidad	Trinidad	34		43			Trinidad	73		37		132		121
Other International (1)		(7)		(1)
Other International (1) (2)							Other International (1) (2)	(15)		(21)		(29)		31
Total	Total	546		932			Total	3,664		1,471		7,113		3,574
Reconciling Items	Reconciling Items						Reconciling Items
Other Expense, Net		(1)		(4)
Other Income, Net							Other Income, Net	40		6		66		—
Interest Expense, Net	Interest Expense, Net	(48)		(47)			Interest Expense, Net	(41)		(48)		(137)		(140)
Income Before Income Taxes	Income Before Income Taxes	$	497	$	881		Income Before Income Taxes	$	3,663	$	1,429	$	7,042	$	3,434

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

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

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


		At March 31, 2022		At December 31, 2021			At September 30, 2022		At December 31, 2021
Total Assets	Total Assets					Total Assets
United States	United States	$	37,275	$	37,436	United States	$	39,521	$	37,436
Trinidad	Trinidad	676		637		Trinidad	831		637
Other International (1)	Other International (1)	146		163		Other International (1)	135		163
Total	Total	$	38,097	$	38,236	Total	$	40,487	$	38,236

~~-13-~~-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 ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (in millions):


		Three Months Ended March 31,					Nine Months Ended September 30,
		2022		2021			2022		2021
Carrying Amount at January 1	Carrying Amount at January 1	$	1,231	$	1,217	Carrying Amount at January 1	$	1,231	$	1,217
Liabilities Incurred	Liabilities Incurred	20		12		Liabilities Incurred	83		55
Liabilities Settled (1)	Liabilities Settled (1)	(131)		(5)		Liabilities Settled (1)	(178)		(83)
Accretion	Accretion	11		11		Accretion	32		33
Revisions	Revisions	2		2		Revisions	102		(7)
Carrying Amount at March 31		$	1,133	$	1,237
Foreign Currency Translation						Foreign Currency Translation	(5)		—
Carrying Amount at September 30						Carrying Amount at September 30	$	1,265	$	1,215

Current Portion	Current Portion	$	41	$	49	Current Portion	$	38	$	54
Noncurrent Portion	Noncurrent Portion	$	1,092	$	1,188	Noncurrent Portion	$	1,227	$	1,161

(1)Includes settlements related to asset sales.

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

7. Exploratory Well Costs

EOG's net changes in capitalized exploratory well costs for the ~~three-month~~nine-month period ended ~~March 31,~~September 30, 2022, are presented below (in millions):


	~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022
Balance at January 1	$	7
Additions Pending the Determination of Proved Reserves	1693
Reclassifications to Proved Properties	(12)
Costs Charged to Expense (1)	~~(1)~~(35)
Balance at ~~March 31~~September 30	$	1053

(1)Includes capitalized exploratory well costs charged to either dry hole costs or impairments.

At ~~March 31,~~September 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.

~~-14-~~-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 ~~$12~~$37 million and $36 million for ~~each of~~ the ~~three~~nine months ended ~~March 31,~~September 30, 2022 and 2021. In addition, EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan, both of which are available to most of the employees of the Trinidadian subsidiary, the costs of which are not material.

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

10. Long-Term Debt and Common Stock

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

At ~~March 31,~~September 30, 2022, the $1,250 million aggregate principal amount of EOG's 2.625% Senior Notes due 2023 were classified as Current Portion of Long-Term Debt on the Condensed Consolidated Balance Sheets.

EOG currently has a $2.0 billion senior unsecured Revolving Credit Agreement (Agreement) with domestic and foreign lenders (Banks). The Agreement has a scheduled maturity date of June 27, 2024, and includes an option for EOG to extend, on up to two occasions, the term for successive one-year periods subject to certain terms and conditions. The Agreement (i) commits the Banks to provide advances up to an aggregate principal amount of $2.0 billion at any one 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) includes a swingline subfacility and a letter of credit subfacility. Advances under the Agreement will accrue interest based, at EOG's option, on either LIBOR plus an applicable margin (Eurodollar rate) or the base rate (as defined in the Agreement) plus an applicable margin. The Agreement contains representations, warranties, covenants and events of default that EOG believes are customary for investment-grade, senior unsecured commercial bank credit agreements, including a financial covenant for the maintenance of a ratio of total debt-to-capitalization (as such terms are defined in the Agreement) of no greater than 65%. At ~~March 31,~~September 30, 2022, EOG was in compliance with this financial covenant. At ~~March 31,~~September 30, 2022 and December 31, 2021, there were no borrowings or letters of credit outstanding under the Agreement. The Eurodollar rate and base rate (inclusive of the applicable margin), had there been any amounts borrowed under the Agreement at ~~March 31,~~September 30, 2022, would have been ~~1.35%~~4.04% and ~~3.50%~~6.25%, respectively.

Common Stock. On February 24, 2022, the 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 ~~payable~~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 ~~payable~~paid on June 30, 2022, to stockholders of record as of June 15, 2022.

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

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

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

~~-15-~~-16-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

11. Fair Value Measurements

Recurring Fair Value Measurements. As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's 2021 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 ~~March 31,~~September 30, 2022 and December 31, 2021 (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 March 31, 2022
At September 30, 2022										At September 30, 2022
Financial Assets:	Financial Assets:									Financial Assets:
Natural Gas Basis Swaps	Natural Gas Basis Swaps	$	—	$	23	$	—	$	23	Natural Gas Basis Swaps	$	—	$	29	$	—	$	29
Financial Liabilities:	Financial Liabilities:									Financial Liabilities:
Crude Oil Swaps	Crude Oil Swaps	—		1,663		—		1,663		Crude Oil Swaps	—		297		—		297
Natural Gas Swaps	Natural Gas Swaps	—		1,091		—		1,091		Natural Gas Swaps	—		1,052		—		1,052
Crude Oil Roll Differential Swaps	Crude Oil Roll Differential Swaps	—		54		—		54		Crude Oil Roll Differential Swaps	—		8		—		8

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

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

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.

~~-16-~~-17-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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

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

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 ~~March 31,~~September 30, 2022 and December 31, 2021, EOG had outstanding $4,890 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately ~~$5,221~~$4,667 million and $5,577 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.

~~-17-~~-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 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 ~~three-month~~nine-month period ended ~~March 31,~~September 30, 2022 (closed) and outstanding as of ~~March 31,~~September 30, 2022. 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	Crude Oil Financial Price Swap Contracts								Crude Oil Financial Price Swap Contracts
			Contracts Sold			Contracts Purchased					Contracts Sold			Contracts Purchased
Period	Period	Settlement Index	Volume (MBbld)	Weighted Average Price ($/Bbl)		Volume (MBbld)	Weighted Average Price ($/Bbl)		Period	Settlement Index	Volume (MBbld)	Weighted Average Price ($/Bbl)		Volume (MBbld)	Weighted Average Price ($/Bbl)

January - March 2022 (closed)	January - March 2022 (closed)	New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI)	140	$	65.58	—	$	—	January - March 2022 (closed)	New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI)	140	$	65.58	—	$	—
April - June 2022		NYMEX WTI	140	65.62		—	—
July - September 2022		NYMEX WTI	140	65.59		—	—
April - June 2022 (closed)									April - June 2022 (closed)	NYMEX WTI	140	65.62		—	—
July - September 2022 (closed)									July - September 2022 (closed)	NYMEX WTI	140	65.59		—	—
October - December 2022 (closed) (1)									October - December 2022 (closed) (1)	NYMEX WTI	53	66.11		—	—
October - December 2022	October - December 2022	NYMEX WTI	140	65.68		78	88.73		October - December 2022	NYMEX WTI	87	65.41		87	88.85
January - March 2023 (closed) (1) (2)									January - March 2023 (closed) (1) (2)	NYMEX WTI	55	67.96		—	—
January - March 2023	January - March 2023	NYMEX WTI	150	67.92		—	—		January - March 2023	NYMEX WTI	95	67.90		6	102.26
April - June 2023		NYMEX WTI	120	67.79		—	—
July - September 2023		NYMEX WTI	100	70.15		—	—
October - December 2023		NYMEX WTI	69	69.41		—	—
April - May 2023 (closed) (1)									April - May 2023 (closed) (1)	NYMEX WTI	29	68.28		—	—
April - May 2023									April - May 2023	NYMEX WTI	91	67.63		2	98.15
June 2023 (closed) (1)									June 2023 (closed) (1)	NYMEX WTI	118	67.77		—	—
June 2023									June 2023	NYMEX WTI	2	69.10		2	98.15
July - September 2023 (closed) (1)									July - September 2023 (closed) (1)	NYMEX WTI	100	70.15		—	—
October - December 2023 (closed) (1)									October - December 2023 (closed) (1)	NYMEX WTI	69	69.41		—	—

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

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

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

-19-

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Crude Oil Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MBbld)

Weighted Average Price Differential
($/Bbl)

January - October 2022 (closed)

NYMEX WTI Roll Differential (1)

125

0.15

November - December 2022

NYMEX WTI Roll Differential (1)

125

0.15

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


Natural Gas Financial Price Swap Contracts
		Contracts Sold
Period	Settlement Index	Volume (MMBtud in thousands)	Weighted Average Price ($/MMBtu)

January - September 2022 (closed)	NYMEX Henry Hub	725	$	3.57
October - December 2022 (closed) (1)	NYMEX Henry Hub	425	3.05
October (closed)	NYMEX Henry Hub	300	4.32
November - December 2022	NYMEX Henry Hub	300	4.32
January - December 2023 (closed) (1)	NYMEX Henry Hub	425	3.05
January - December 2023	NYMEX Henry Hub	300	3.36
January - December 2024	NYMEX Henry Hub	725	3.07
January - December 2025	NYMEX Henry Hub	725	3.07

~~-18-~~

(1) In the second quarter of 2022, EOG ~~RESOURCES, INC.~~

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

~~(Unaudited)~~

Natural Gas Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price
($/MMBtu)
January - April 2022 (closed) NYMEX Henry Hub 725 $ 3.57
May - December 2022 NYMEX Henry Hub 725 3.57
January - December 2023 NYMEX Henry Hub 725 3.18
January - December 2024 NYMEX Henry Hub 725 3.07
January - December 2025 NYMEX Henry Hub 725 3.07
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 - March 2022 (closed)

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

210

(0.01)

April - December 2022

NYMEX Henry Hub HSC Differential (1)

210

(0.01)

January - September 2022 (closed)

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

210

0.01

October - December 2022

NYMEX Henry Hub HSC Differential (1)

210

0.01

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

(0.01)

January - December 2023

NYMEX Henry Hub HSC Differential (1)

135

0.01

January - December 2024

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2024

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2025

NYMEX Henry Hub HSC Differential (1)

0.00

January - December 2025

NYMEX Henry Hub HSC Differential (1)

0.00

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

~~-19-~~-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 ~~March 31,~~September 30, 2022 and December 31, 2021. 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

March 31, 2022

December 31, 2021

Description

Location on Balance Sheet

September 30, 2022

December 31, 2021

Asset Derivatives

Crude oil and natural gas derivative contracts -

Noncurrent Portion

Other Assets (1)

—

Noncurrent Portion

Other Assets (1)

—

Liability Derivatives

Crude oil and natural gas derivative contracts -

Current portion

Liabilities from Price Risk Management Activities (2)

260

269

Current portion

Liabilities from Price Risk Management Activities (2)

243

269

Noncurrent portion

Other Liabilities (3)

110

Noncurrent portion

Other Liabilities (3)

399

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

(2) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$1,948~~$547 million, partially offset by gross assets of ~~$13~~$25 million and collateral posted with counterparties of ~~$1,675~~$279 million at ~~March 31,~~September 30, 2022. The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $421 million, partially offset by gross assets of $29 million and collateral posted with counterparties of $123 million, at December 31, 2021.

(3) The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of ~~$860~~$810 million, partially offset by gross assets of ~~$10~~$4 million and collateral posted with counterparties of ~~$740~~$407 million at ~~March 31,~~September 30, 2022. The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $64 million, partially offset by gross assets of $10 million and collateral posted with counterparties of $17 million, at December 31, 2021.

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 ~~March 31,~~September 30, 2022 and December 31, 2021. EOG had ~~$2,415~~$686 million of collateral posted and no collateral held at ~~March 31,~~September 30, 2022. EOG had $140 million of collateral posted and no collateral held at December 31, 2021. Due to changes in contracted volumes and commodity prices subsequent to ~~March 31,~~September 30, 2022, EOG had ~~$2,900~~$623 million of collateral posted at ~~May 4,~~November 2, 2022.

-21-

13. Acquisitions and Divestitures

During the ~~three~~nine months ended ~~March 31,~~September 30, 2022, EOG paid cash for property acquisitions of $392 million in the United States. Additionally, during the nine months ended September 30, 2022, EOG recognized net gains on asset dispositions of ~~$25~~$101 million and received proceeds of approximately ~~$121~~$310 million, primarily due to the sale of certain legacy natural gas assets in the Rocky Mountain area, unproved leasehold in Texas and producing properties in the Mid-Continent area.

During the ~~three~~nine months ended ~~March 31,~~September 30, 2021, EOG paid cash for property acquisitions of $6$95 million in the United States. Additionally, during the ~~three~~nine months ended ~~March 31,~~September 30, 2021, EOG recognized net ~~losses~~gains on asset dispositions of $6$46 million and received proceeds of approximately ~~$5 million.~~$154 million, primarily due to the sale of its China operations during the second quarter of 2021.

~~-20-~~-22-

PART I. FINANCIAL INFORMATION

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EOG RESOURCES, INC.

Overview

EOG Resources, Inc., together with its subsidiaries (collectively, EOG), is one of the largest independent (non-integrated) crude oil and natural gas companies in the United States with proved reserves in the United States and Trinidad. 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 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 ~~three~~nine months of 2022, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were ~~$94.38~~$98.14 per barrel and ~~$4.91~~$6.77 per million British thermal units (MMBtu), respectively, representing increases of ~~63%~~51% and ~~83%~~113%, respectively, from the average NYMEX prices for the same period in 2021. Market prices for NGLs are influenced by the components extracted, including ethane, propane and butane and natural gasoline, among others, and the respective market pricing for each component.

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

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

-23-

Such inflationary pressures on EOG's operating costs have, in turn, impacted its cash flows and results of operations. However, by virtue of its continued focus on increasing its drilling, completion and operating efficiencies and improving the performance of its wells, as well as the flexibility provided by its multi-basin drilling portfolio, EOG has, to date, been able to largely offset such impacts. EOG currently expects such inflationary pressures to result in an increase of less than 10 percent in its fiscal year 2022 well costs (i.e., its costs for drilling, completions and well-site facilities) versus fiscal year 2021. Accordingly, such increase in EOG's fiscal year 2022 well costs has not, to date, had a material impact on EOG's results of operations, and EOG currently does not expect such increase to have a material impact on its full-year 2022 results of operations. Further, such inflationary pressures and the factors contributing to such inflationary pressures (described above) have not, to date, impacted EOG's liquidity, capital resources, cash requirements or financial position or its ability to conduct its day-to-day drilling, completion and production operations.

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

EOG plans to continue with these initiatives and actions, though there can be no assurance that such efforts will offset, largely or at all, the impacts of any future inflationary pressures on EOG's operating 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.

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 ~~to a lesser extent,~~ natural gas plays.

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

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

~~-21-~~

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

-24-

Also, in the first nine months of 2022, EOG ~~continues~~continued to make progress on the design, fabrication and ~~fabrication~~installation of athe platform and related facilities for its ~~previously announced~~previously-announced discovery in the Modified U(a) Block. In the fourth quarter of 2022, EOG expects to ~~install~~complete the installation of the platform ~~together with the related~~and facilities and commence the development drilling campaign in the Modified U(a) Block. Additionally, in the first nine months of 2022, EOG commenced the drilling of one net exploratory well from a pre-existing platform in the Modified U(a) Block, which was in progress at September 30, 2022. In the fourth quarter of 2022, EOG also expects to complete and put on production one net exploratory well that was started in the third quarter of 2022 and to drill ~~three development wells and~~ one additional net exploratory ~~well.~~well from the same platform.

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 the first nine months of 2022, EOG ~~continues~~continued to prepare for the drilling of an exploration well which is expected to commence in ~~2023.~~2023, subject to statutory approvals.

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.

2022 Capital and Operating Plan. Total 2022 capital expenditures are estimated to range from approximately ~~$4.3~~$4.5 billion to $4.7 billion, including facilities and gathering, processing 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. To further enhance the economics of these plays, EOG expects to continue to improve well performance and to mitigate recent inflationary ~~pressure~~pressures on its operating and capital costs (e.g., costs for fuel and tubulars) through efficiency ~~gains.~~gains; see above related discussion. Full-year 2022 total crude oil, NGLs and natural gas production is expected to return to ~~prepandemic~~pre-pandemic levels. In addition, EOG ~~expects~~plans to continue to spend a portion of its anticipated 2022 capital expenditures on leasing acreage, evaluating new prospects, ~~long-term~~ transportation infrastructure and environmental projects.

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

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

At ~~March 31,~~September 30, 2022, EOG maintained a strong financial and liquidity position, including ~~$4.0~~$5.3 billion of cash and cash equivalents on hand and $2.0 billion of availability under its senior unsecured revolving credit facility.

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 ~~payable~~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 ~~payable~~paid on June 30, 2022, to stockholders of record as of June 15, 2022.

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

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

~~-22-~~

-25-

Cash Return Framework. Also on May 5, 2022, EOG announced the addition of quantitative guidance to its cash return framework - specifically, a commitment to return a minimum of 60% of annual ~~free~~net cash ~~flow~~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. Free cash flow (which is a non-GAAP measure) is computed as EOG's net cash provided by operating activities (a GAAP measure) before certain balance sheet-related changes, less total capital expenditures (a non-GAAP measure). 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 Annual Report on Form 10-K for the year ended December 31, 2021, filed on February 24, ~~2022.~~2022 (EOG's 2021 Annual Report).

Results of Operations

The following review of operations for the three months ended ~~March 31,~~September 30, 2022 and 2021 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 ~~March 31,~~September 30, 2022 vs. Three Months Ended ~~March 31,~~September 30, 2021

Operating Revenues and Other. During the ~~first~~third quarter of 2022, operating revenues increased ~~$289~~$2,828 million, or 8%59%, to ~~$3,983~~$7,593 million from ~~$3,694~~$4,765 million for the same period of 2021. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the ~~first~~third quarter of 2022 increased ~~$2,096~~$1,992 million, or ~~66%~~49%, to ~~$5,286~~$6,037 million from ~~$3,190~~$4,045 million for the same period of 2021. EOG recognized net losses on the mark-to-market of financial commodity derivative contracts of ~~$2,820~~$18 million for the ~~first~~third quarter of 2022 compared to net losses of ~~$367~~$494 million for the same period of 2021. Gathering, processing and marketing revenues for the ~~first~~third quarter of 2022 increased ~~$621~~$375 million, or ~~73%~~32%, to ~~$1,469~~$1,561 million from ~~$848~~$1,186 million for the same period of 2021. Net ~~gains~~losses on asset dispositions were ~~$25~~$21 million for the ~~first~~third quarter of 2022 compared to net ~~losses~~gains of $6$1 million for the same period of 2021.

~~-23-~~-26-

Wellhead volume and price statistics for the three-month periods ended ~~March 31,~~September 30, 2022 and 2021 were as follows:


		Three Months Ended March 31,					Three Months Ended September 30,
		2022		2021			2022			2021
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	449.4		428.7		United States	464.6			448.3
Trinidad	Trinidad	0.7		2.2		Trinidad	0.5			1.2
Other International (2)	Other International (2)	—		0.1		Other International (2)	—			—
Total	Total	450.1		431.0		Total	465.1			449.5
Average Crude Oil and Condensate Prices ($/Bbl) (3)	Average Crude Oil and Condensate Prices ($/Bbl) (3)					Average Crude Oil and Condensate Prices ($/Bbl) (3)
United States	United States	$	96.02	$	58.07	United States	$	96.05		$	70.88
Trinidad	Trinidad	83.82		49.77		Trinidad	84.98			60.19
Other International (2)	Other International (2)	—		38.61		Other International (2)	—			—
Composite	Composite	96.00		58.02		Composite	96.04			70.85
Natural Gas Liquids Volumes (MBbld) (1)	Natural Gas Liquids Volumes (MBbld) (1)					Natural Gas Liquids Volumes (MBbld) (1)
United States	United States	190.3		124.3		United States	209.3			157.9
Total	Total	190.3		124.3		Total	209.3			157.9
Average Natural Gas Liquids Prices ($/Bbl) (3)	Average Natural Gas Liquids Prices ($/Bbl) (3)					Average Natural Gas Liquids Prices ($/Bbl) (3)
United States	United States	$	39.77	$	28.03	United States	$	36.02		$	37.72
Composite	Composite	39.77		28.03		Composite	36.02			37.72
Natural Gas Volumes (MMcfd) (1)	Natural Gas Volumes (MMcfd) (1)					Natural Gas Volumes (MMcfd) (1)
United States	United States	1,249		1,100		United States	1,306			1,210
Trinidad	Trinidad	209		217		Trinidad	163			212
Other International (2)	Other International (2)	—		25		Other International (2)	—			—
Total	Total	1,458		1,342		Total	1,469			1,422
Average Natural Gas Prices ($/Mcf) (3)	Average Natural Gas Prices ($/Mcf) (3)					Average Natural Gas Prices ($/Mcf) (3)
United States	United States	$	5.81	$	5.52	United States	$	9.35		$	4.50
Trinidad	Trinidad	3.36		3.38		Trinidad	7.45		(5)	3.39
Other International (2)	Other International (2)	—		5.66		Other International (2)	—			—
Composite	Composite	5.46		5.17		Composite	9.14			4.34
Crude Oil Equivalent Volumes (MBoed) (4)	Crude Oil Equivalent Volumes (MBoed) (4)					Crude Oil Equivalent Volumes (MBoed) (4)
United States	United States	847.8		736.4		United States	891.6			807.9
Trinidad	Trinidad	35.5		38.5		Trinidad	27.6			36.5
Other International (2)	Other International (2)	—		4.0		Other International (2)	—			—
Total	Total	883.3		778.9		Total	919.2			844.4

Total MMBoe (4)	Total MMBoe (4)	79.5		70.1		Total MMBoe (4)	84.6			77.7

(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)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.

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

~~-24-~~-27-

Wellhead crude oil and condensate revenues for the ~~first~~third quarter of 2022 increased ~~$1,638~~$1,180 million, or ~~73%~~40%, to ~~$3,889~~$4,109 million from ~~$2,251~~$2,929 million for the same period of 2021. The increase was due to a higher composite average price ($~~1,539~~1,087 million) and an increase of ~~19.1~~15.6 MBbld, or 4%3%, in wellhead crude oil and condensate production ($9993 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~~third quarter of 2022 increased ~~65%~~36% to ~~$96.00~~$96.04 per barrel compared to ~~$58.02~~$70.85 per barrel for the same period of 2021.

NGL revenues for the ~~first~~third quarter of 2022 increased ~~$367~~$145 million, or ~~117%~~26%, to ~~$681~~$693 million from ~~$314~~$548 million for the same period of 2021 due to ~~a higher composite average price ($202 million) and~~ an increase of ~~66.0~~51.4 MBbld, or ~~53%~~33%, in NGL deliveries ($~~165~~177 million), partially offset by a lower composite average price ($32 million). Increased production was primarily infrom the Permian Basin. EOG's composite NGL price for the ~~first~~third quarter of 2022 ~~increased 42%~~decreased 5% to ~~$39.77~~$36.02 per barrel compared to ~~$28.03~~$37.72 per barrel for the same period of 2021.

Wellhead natural gas revenues for the ~~first~~third quarter of 2022 increased ~~$91~~$667 million, or ~~15%~~117%, to ~~$716~~$1,235 million from ~~$625~~$568 million for the same period of 2021. The increase was due to a higher average composite price ($650 million) and an increase in natural gas deliveries ($~~53 million) and a higher average composite price ($38~~17 million). Natural gas deliveries for the ~~first~~third quarter of 2022 increased ~~116~~47 MMcfd, or 9%3%, compared to the same period of 2021 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 deliveries in Trinidad and lower natural gas volumes ~~associated with~~due to the ~~disposition~~sale of ~~the China~~certain legacy natural gas assets in the ~~second~~Rocky Mountain area in the first quarter of ~~2021.~~2022. EOG's composite wellhead natural gas price for the ~~first~~third quarter of 2022 increased 6%111% to ~~$5.46~~$9.14 per Mcf compared to ~~$5.17~~$4.34 per Mcf for the same period of 2021.

During the ~~first~~third quarter of 2022, EOG recognized net losses on the mark-to-market of financial commodity derivative contracts of ~~$2,820~~$18 million compared to net losses of ~~$367~~$494 million for the same period of 2021. During the ~~first~~third quarter of 2022, net cash paid for settlements of financial commodity derivative contracts was ~~$296~~$847 million, ~~compared~~of which $63 million was related to ~~net~~the early termination of certain contracts scheduled to settle after December 31, 2022. Net cash paid for settlements of financial commodity derivative contracts ~~of $30~~was $293 million for the same period of 2021.

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 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 ~~first~~third quarter of 2022 ~~increased $176~~decreased $62 million as compared to the same period of 2021 primarily due to ~~higher~~lower margins on crude oil ~~and~~marketing activities, partially offset by higher margins on natural gas marketing activities.

~~-25-~~-28-

Operating and Other Expenses. For the ~~first~~third quarter of 2022, operating expenses of ~~$3,437~~$3,929 million were ~~$675~~$635 million higher than the ~~$2,762~~$3,294 million incurred during the ~~first~~third quarter of 2021. The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended ~~March 31,~~September 30, 2022 and 2021:


		Three Months Ended March 31,					Three Months Ended September 30,
		2022		2021			2022		2021
Lease and Well	Lease and Well	$	4.00	$	3.85	Lease and Well	$	3.96	$	3.48
Transportation Costs	Transportation Costs	2.87		2.88		Transportation Costs	3.04		2.82
Gathering and Processing Costs	Gathering and Processing Costs	1.81		1.98		Gathering and Processing Costs	1.97		1.87
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	10.19		12.31		Oil and Gas Properties	10.24		11.47
Other Property, Plant and Equipment	Other Property, Plant and Equipment	0.46		0.53		Other Property, Plant and Equipment	0.47		0.46
General and Administrative (G&A)	General and Administrative (G&A)	1.56		1.57		General and Administrative (G&A)	1.92		1.83
Interest Expense, Net	Interest Expense, Net	0.60		0.67		Interest Expense, Net	0.48		0.62
Total (1)	Total (1)	$	21.49	$	23.79	Total (1)	$	22.08	$	22.55

(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~~net interest expense for the three months ended ~~March 31,~~September 30, 2022, compared to the same period of 2021, are set forth below. See "Operating Revenues and Other" 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 ~~$318~~$335 million for the ~~first~~third quarter of 2022 increased ~~$48~~$65 million from $270 million for the same prior year period primarily due to increased operating and maintenance costs ($3560 million) and increased ~~workovers~~workover expenditures ($118 million), both 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 ~~$228~~$257 million for the ~~first~~third quarter of 2022 increased ~~$26~~$38 million from ~~$202~~$219 million for the same prior year period primarily due to increased transportation costs related to production from the Permian ~~Basin ($20 million), the Eagle Ford oil play ($5 million) and the Rocky Mountain area ($4 million).~~Basin.

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.

~~-26-~~-29-

Gathering and processing costs increased $5$22 million to ~~$144~~$167 million for the ~~first~~third quarter of 2022 compared to ~~$139~~$145 million for the same prior year period primarily due to increased gathering and processing fees ~~($16 million) and operating and maintenance expense ($8 million), both~~ related to production from the Permian ~~Basin;~~Basin ($22 million) and increased operating and maintenance expenses related to production from the Permian Basin ($14 million) and the Eagle Ford oil play ($5 million), partially offset by decreased gathering and processing fees inrelated to production from the Eagle Ford oil play ($911 million) and ~~decreased operating and maintenance expenses~~due to the sale of certain legacy natural gas assets in ~~the Eagle Ford oil play ($6 million) and~~ the Rocky Mountain area in the first quarter of 2022 ($49 million).

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

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

DD&A expenses for the ~~first~~third quarter of 2022 decreased ~~$53~~$21 million to ~~$847~~$906 million from ~~$900~~$927 million for the same prior year period. DD&A expenses associated with oil and gas properties for the ~~first~~third quarter of 2022 were ~~$53~~$24 million lower than the same prior year period. The decrease primarily reflects ~~lower~~decreased unit rates in the United States ($~~172~~108 million) and decreased production in Trinidad ($4 million), partially offset by increased production in the United States ($~~125~~89 million). Unit rates in the United States decreased primarily due to upward reserve revisions related to higher average crude oil, NGL and natural gas prices used in the reserve estimation process and to reserves added at lower costs as a result of increased efficiencies.

~~G&A expenses~~Exploration costs of ~~$124~~$35 million for the ~~first~~third quarter of 2022 ~~increased $14~~decreased $9 million from ~~$110 million for the same prior year period primarily due to increased employee-related costs.~~

~~Exploration costs of $45 million for the first quarter of 2022 increased $12 million from $33~~$44 million for the same prior year period due primarily to ~~increased~~decreased geological and geophysical expenditures in the United States.

Interest expense, net of $41 million for the third quarter of 2022 decreased $7 million compared to the same prior year period primarily due to decreased interest expense on certain royalty payments.

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.

~~-27-~~

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


		Three Months Ended March 31,					Three Months Ended September 30,
		2022		2021			2022		2021
Proved properties	Proved properties	$	1	$	—	Proved properties	$	45	$	13
Unproved properties	Unproved properties	54		43		Unproved properties	49		69
Firm commitment contracts		—		1

Total	Total	$	55	$	44	Total	$	94	$	82

-30-

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

Taxes other than income for the ~~first~~third quarter of 2022 increased ~~$175~~$57 million to ~~$390~~$334 million ~~(7.4%~~(5.5% of wellhead revenues) from ~~$215~~$277 million ~~(6.7%~~(6.8% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased severance/production taxes ($~~131~~145 million), and increased ad valorem/property taxes ($3827 million) ~~and~~, partially offset by increased ~~payroll taxes~~state severance tax refunds ($6116 million), all in the United States.

Other income, net was $40 million for the third quarter of 2022 compared to other income, net of $6 million for the same prior year period. The change of $34 million in the third quarter of 2022 was primarily due to increased interest income ($30 million) and higher equity income from ammonia plants in Trinidad ($4 million).

EOG recognized an income tax provision of ~~$107~~$809 million for the ~~first~~third quarter of 2022 compared to an income tax provision of ~~$204~~$334 million for the ~~first~~third quarter of 2021, primarily due to increased pretax income. The net effective tax rate for the third quarter of 2022 decreased to 22% from 23% for the third quarter of 2021.

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

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

-31-

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


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

Total MMBoe	247.8			223.1

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

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

-32-

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

NGL revenues for the first nine months of 2022 increased $922 million, or 75%, to $2,151 million from $1,229 million for the same period of 2021 due to an increase of 60.2 MBbld, or 43%, in NGL deliveries ($527 million) and a higher composite average price ($395 million). Increased production was primarily from the Permian Basin. EOG's composite NGL price for the first nine months of 2022 increased 23% to $39.29 per barrel compared to $32.07 per barrel for the same period of 2021.

Wellhead natural gas revenues for the first nine months of 2022 increased $1,354 million, or 85%, to $2,951 million from $1,597 million for the same period of 2021. The increase was due to a higher composite wellhead natural gas price ($1,262 million) and an increase in natural gas deliveries ($92 million). Natural gas deliveries for the first nine months of 2022 increased 82 MMcfd, or 6%, compared to the same period of 2021 due primarily to higher deliveries in the Dorado gas play and increased production of associated natural gas from the Permian Basin, 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 natural gas volumes associated with the disposition of the China assets in the second quarter of 2021. EOG's composite wellhead natural gas price for the first nine months of 2022 increased 75% to $7.28 per Mcf compared to $4.17 per Mcf for the same period of 2021.

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

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

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


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

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

-33-

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

Lease and well expenses of $977 million for the first nine months of 2022 increased $167 million from $810 million for the same prior year period primarily due to increased operating and maintenance costs ($135 million) and increased workover expenditures ($32 million), both 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 of $729 million for the first nine months of 2022 increased $94 million from $635 million for the same prior year period primarily due to increased transportation costs related to production from the Permian Basin ($75 million), the Eagle Ford oil play ($14 million) and the Dorado gas play ($7 million).

Gathering and processing costs increased $51 million to $463 million for the first nine months of 2022 compared to $412 million for the same prior year period primarily due to increased gathering and processing fees related to production from the Permian Basin ($54 million) and increased operating and maintenance expenses related to production from the Permian Basin ($34 million) and the Eagle Ford oil play ($7 million), partially offset by decreased gathering and processing fees related to production from the Eagle Ford oil play ($28 million) and due to the sale of certain legacy natural gas assets in the Rocky Mountain area in the first quarter of 2022 ($19 million).

G&A expenses of $414 million for the first nine months of 2022 increased $42 million from $372 million for the same prior year period primarily due to increased professional and other services ($22 million) and employee-related costs ($21 million).

DD&A expenses for the first nine months of 2022 decreased $77 million to $2,664 million from $2,741 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first nine months of 2022 were $81 million lower than the same prior year period. The decrease primarily reflects decreased unit rates in the United States ($379 million) and in Trinidad ($7 million), decreased production in Trinidad ($10 million) and decreased production associated with the disposition of the China assets in the second quarter of 2021 ($5 million), partially offset by increased production in the United States ($321 million). Unit rates in the United States decreased primarily due to upward reserve revisions related to higher average crude oil, NGL and natural gas prices used in the reserve estimation process and to reserves added at lower costs as a result of increased efficiencies.

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


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

-34-

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

Other income, net was $66 million for the first nine months of 2022 compared to other income, net of zero for the same prior year period. The change of $66 million in the first nine months of 2022 was primarily due to increased interest income ($36 million) and higher equity income from ammonia plants in Trinidad ($27 million).

EOG recognized an income tax provision of $1,560 million for the first nine months of 2022 compared to an income tax provision of $755 million for the first nine months of 2021, primarily due to increased pretax income. The net effective tax rate for the first ~~quarter~~nine months of 2022 ~~decreased to~~was unchanged from the prior year tax rate of 22% ~~from 23% for the first quarter of 2021.~~.

Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the ~~three~~nine months ended ~~March 31,~~September 30, 2022, were funds generated from operations and proceeds from sales of assets. The primary uses of cash were ~~collateral posted for financial commodity derivative contracts;~~ funds used in operations; dividend payments to stockholders; exploration and development expenditures; net cash paid for settlements of financial commodity derivative ~~contracts~~contracts; net collateral posted for financial commodity derivative contracts; and other property, plant and equipment expenditures. During the first ~~three~~nine months of 2022, EOG's cash balance ~~decreased $1,200~~increased $63 million to ~~$4,009~~$5,272 million from $5,209 million at December 31, 2021.

Net cash provided by operating activities of ~~$828~~$7,649 million for the first ~~three~~nine months of 2022 ~~decreased $1,042~~increased $2,024 million compared to the same period of 2021 primarily due to an increase in ~~collateral posted~~wellhead revenues ($7,094 million) and an increase in gathering, processing and marketing revenues less marketing costs ($125 million), partially offset by an increase in net cash paid for settlements of financial commodity derivative contracts ($~~2,275)~~2,741 million), an unfavorable change in net cash paid for income taxes ($1,284 million), an increase in cash operating expenses ($832 million), net cash used in working capital and other assets and liabilities in the first ~~three~~nine months of 2022 ($~~891~~999 million) compared to net cash used in working capital and other assets and liabilities in the first ~~three~~nine months of 2021 ($~~352~~590 million), and an increase in net ~~cash paid~~collateral posted for ~~settlements of~~ financial commodity derivative contracts ($266 million) and an increase in cash operating expenses ($264 million), partially offset by an increase in wellhead revenues ($2,096 million) and an increase in gathering, processing and marketing revenues less marketing costs ($176238 million).

Net cash used in investing activities of ~~$956~~$3,659 million for the first ~~three~~nine months of 2022 increased ~~$135~~$1,077 million compared to the same period of 2021 due to an increase in additions to oil and gas properties ($701 million), net cash used in working capital associated with investing activities in the first ~~three~~nine months of 2022 ($68301 million) compared to net cash provided by working capital associated with investing activities in the first ~~three~~nine months of 2021 ($91100 million), ~~an increase in additions to oil and gas properties ($64 million) and~~ an increase in additions to other property, plant and equipment ($28101 million) and an increase in other investing activities ($30 million), partially offset by an increase in proceeds from the sale of assets ($~~116~~156 million).

~~-28-~~

Net cash used in financing activities of ~~$1,072~~$3,926 million for the first ~~three~~nine months of 2022 included cash dividend payments ($~~1,023~~3,821 million), purchases of treasury stock in connection with stock compensation plans ($4395 million) and repayment of finance lease liabilities ($1027 million). Net cash used in financing activities of ~~$988~~$2,079 million for the first ~~three~~nine months of 2021 included cash dividend payments ($1,278 million), repayments of long-term debt ($750 ~~million), cash dividend payments ($219~~ million), purchases of treasury stock in connection with stock compensation plans ($1033 million) and repayment of finance lease liabilities ($927 million).

-35-

Total Expenditures. For the year 2022, EOG's updated budget for exploration and development and other property, plant and equipment expenditures is estimated to range from approximately ~~$4.3~~$4.5 billion to $4.7 billion, excluding acquisitions, non-cash transactions and exploration costs. The table below sets out components of total expenditures for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021 (in millions):


		Three Months Ended March 31,					Nine Months Ended September 30,
		2022		2021			2022		2021
Expenditure Category	Expenditure Category					Expenditure Category
Capital	Capital					Capital
Exploration and Development Drilling	Exploration and Development Drilling	$	813	$	733	Exploration and Development Drilling	$	2,599	$	2,097
Facilities	Facilities	109		82		Facilities	291		287
Leasehold Acquisitions (1)	Leasehold Acquisitions (1)	64		58		Leasehold Acquisitions (1)	148		194
Property Acquisitions (2)	Property Acquisitions (2)	5		9		Property Acquisitions (2)	398		99
Capitalized Interest	Capitalized Interest	8		8		Capitalized Interest	26		24
Subtotal	Subtotal	999		890		Subtotal	3,462		2,701
Exploration Costs	Exploration Costs	45		33		Exploration Costs	115		112
Dry Hole Costs	Dry Hole Costs	3		11		Dry Hole Costs	41		28
Exploration and Development Expenditures	Exploration and Development Expenditures	1,047		934		Exploration and Development Expenditures	3,618		2,841
Asset Retirement Costs	Asset Retirement Costs	27		17		Asset Retirement Costs	209		56
Total Exploration and Development Expenditures	Total Exploration and Development Expenditures	1,074		951		Total Exploration and Development Expenditures	3,827		2,897
Other Property, Plant and Equipment (3)	Other Property, Plant and Equipment (3)	70		116		Other Property, Plant and Equipment (3)	248		221
Total Expenditures	Total Expenditures	$	1,144	$	1,067	Total Expenditures	$	4,075	$	3,118

(1) Leasehold acquisitions included ~~$58~~$107 million and ~~$22~~$37 million for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021, respectively, related to non-cash property exchanges.

(2) Property acquisitions included $5$6 million and $3$4 million for the ~~three-month~~nine-month periods ended ~~March 31,~~September 30, 2022 and 2021, respectively, related to non-cash property exchanges.

(3) Other property, plant and equipment included $74 million of non-cash additions for the ~~three-month~~nine-month period ended ~~March 31,~~September 30, 2021, primarily related to finance lease transactions for storage facilities.

Exploration and development expenditures of ~~$1,047~~$3,618 million for the first ~~three~~nine months of 2022 were ~~$113~~$777 million higher than the same period of 2021 primarily due to increased exploration and development drilling expenditures in the United States ($~~94 million), increased facilities expenditures ($27~~520 million) and increased ~~leasehold~~property acquisitions ($6299 million), partially offset by decreased leasehold acquisitions ($46 million) and decreased exploration and development drilling expenditures in ~~Trinidad ($9 million) and~~ Other International ($521 million). Exploration and development expenditures for the first ~~three~~nine months of 2022 of ~~$1,047~~$3,618 million consisted of ~~$907~~$2,822 million in development drilling and facilities, ~~$127~~$398 million in property acquisitions, $372 million in exploration $8and $26 million in capitalized ~~interest and $5 million in property acquisitions.~~interest. Exploration and development expenditures for the first ~~three~~nine months of 2021 of ~~$934~~$2,841 million consisted of ~~$812~~$2,299 million in development drilling and facilities, ~~$105~~$419 million in exploration, $9$99 million in property acquisitions and $8$24 million in capitalized interest.

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

~~-29-~~-36-

Financial Commodity Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2021 Annual Report, ~~on Form 10-K for the year ended December 31, 2021, filed on February 24, 2022,~~ 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 ~~Gains (Losses)~~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 ~~March 31,~~September 30, 2022, as a net liability of ~~$370~~$642 million.

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

Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the period from January 1, 2022 to ~~May 4,~~October 28, 2022 (closed) and outstanding as of ~~May 4,~~October 28, 2022. 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 2022 (closed) NYMEX West Texas Intermediate (WTI) 140 $ 65.58 — $ —
April 2022 (closed) NYMEX WTI 140 65.62 — —
May - June 2022 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 - March 2023 NYMEX WTI 150 67.92 — —
April - June 2023 NYMEX WTI 120 67.79 — —
July - September 2023 NYMEX WTI 100 70.15 — —
October - December 2023 NYMEX WTI 69 69.41 — —

-37-


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

January - March 2022 (closed)	NYMEX West Texas Intermediate (WTI)	140	$	65.58	—	$	—
April - June 2022 (closed)	NYMEX WTI	140	65.62		—	—
July - September 2022 (closed)	NYMEX WTI	140	65.59		—	—
October - December 2022 (closed) (1)	NYMEX WTI	53	66.11		—	—
October - December 2022	NYMEX WTI	87	65.41		87	88.85
January - March 2023 (closed) (1) (2)	NYMEX WTI	55	67.96		—	—
January - March 2023	NYMEX WTI	95	67.90		6	102.26
April - May 2023 (closed) (1)	NYMEX WTI	29	68.28		—	—
April - May 2023	NYMEX WTI	91	67.63		2	98.15
June 2023 (closed) (1)	NYMEX WTI	118	67.77		—	—
June 2023	NYMEX WTI	2	69.10		2	98.15
July - September 2023 (closed) (1)	NYMEX WTI	100	70.15		—	—
October - December 2023 (closed) (1)	NYMEX WTI	69	69.41		—	—

(1) In ~~April~~the second quarter of 2022, EOG executed the early termination provision granting EOG the right to terminate certain of its October 2022 - December ~~2022~~2023 crude oil financial price swap contracts which were open at that time. EOG paid net cash of ~~$114~~$593 million for the settlement of these contracts.

~~-30-~~

Crude Oil Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume
(MBbld)

Weighted Average Price Differential
($/Bbl)

Period

Settlement Index

Volume
(MBbld)

Weighted Average Price Differential
($/Bbl)

January - May 2022 (closed)

NYMEX WTI Roll Differential (1)

125

0.15

June - December 2022

NYMEX WTI Roll Differential (1)

125

0.15

January - November 2022 (closed)

NYMEX WTI Roll Differential (1)

125

0.15

December 2022

NYMEX WTI Roll Differential (1)

125

0.15

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

Natural Gas Financial Price Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price ($/MMBtu)
January - May 2022 (closed) NYMEX Henry Hub 725 $ 3.57
June - December 2022 NYMEX Henry Hub 725 3.57
January - December 2023 NYMEX Henry Hub 725 3.18
January - December 2024 NYMEX Henry Hub 725 3.07
January - December 2025 NYMEX Henry Hub 725 3.07

-38-

Natural Gas Basis Swap Contracts
Contracts Sold
Period Settlement Index Volume
(MMBtud in thousands) Weighted Average Price Differential
($/MMBtu)
January - May 2022 (closed)
NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)
210 $ (0.01)
June - December 2022
NYMEX Henry Hub HSC Differential (1)
210 (0.01)
January - December 2023
NYMEX Henry Hub HSC Differential (1)
135 (0.01)
January - December 2024
NYMEX Henry Hub HSC Differential (1)
10 0.00
January - December 2025
NYMEX Henry Hub HSC Differential (1)
10 0.00


Natural Gas Financial Price Swap Contracts
		Contracts Sold
Period	Settlement Index	Volume (MMBtud in thousands)	Weighted Average Price ($/MMBtu)

January - September 2022 (closed)	NYMEX Henry Hub	725	$	3.57
October - December 2022 (closed) (1)	NYMEX Henry Hub	425	3.05
October - November 2022 (closed)	NYMEX Henry Hub	300	4.32
December 2022	NYMEX Henry Hub	300	4.32
January - December 2023 (closed) (1)	NYMEX Henry Hub	425	3.05
January - December 2023	NYMEX Henry Hub	300	3.36
January - December 2024	NYMEX Henry Hub	725	3.07
January - December 2025	NYMEX Henry Hub	725	3.07

(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)

January - September 2022 (closed)	NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1)	210	$	0.01
October - December 2022	NYMEX Henry Hub HSC Differential (1)	210	0.01
January - December 2023	NYMEX Henry Hub HSC Differential (1)	135	0.01
January - December 2024	NYMEX Henry Hub HSC Differential (1)	10	0.00
January - December 2025	NYMEX Henry Hub HSC Differential (1)	10	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 ~~$2,900~~$623 million of collateral posted at ~~May 4,~~November 2, 2022. EOG expects this collateral to be applied to the settlement of financial commodity derivative contracts if market prices remain above contract prices. The amount of posted collateral will increase or decrease based on fluctuations in forward NYMEX WTI and Henry Hub prices.

~~-31-~~

-39-

Information Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, goals, returns and rates of return, budgets, reserves, levels of production, capital expenditures, costs and asset sales, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for future operations, are forward‐looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "aims," "ambition," "initiative," "goal," "may," "will," "focused on," "should" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward‐looking statements. In particular, statements, express or implied, concerning EOG's future 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 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 assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. 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, operating and capital costs 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 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 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 and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;

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•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; 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;

•EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves, production and drilling, completing and operating costs 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 and other personnel, facilities, equipment, materials (such as water, sand 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;

•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 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.

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

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PART I. FINANCIAL INFORMATION

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

EOG RESOURCES, INC.

EOG's exposure to commodity price risk, interest rate risk and foreign currency exchange rate risk is discussed in (i) the ~~"Financial Commodity~~"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, filed on February 24, 2022 (EOG's 2021 Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements included in EOG's 2021 Annual Report. ~~There have been no material changes in this information.~~ For ~~additional~~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 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 ~~March 31,~~September 30, 2022.

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)
January 1, 2022 - January 31, 2022 62,027 $ 102.94 — $ 5,000,000,000
February 1, 2022 - February 28, 2022 112,866 112.27 — $ 5,000,000,000
March 1, 2022 - March 31, 2022 195,555 119.05 — $ 5,000,000,000
Total 370,448 114.29 —


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


July 1, 2022 - July 31, 2022	6,149	$	108.69	—	$	5,000,000,000
August 1, 2022 - August 31, 2022	18,473	115.99		—	$	5,000,000,000
September 1, 2022 - September 30, 2022	321,946	105.79		—	$	5,000,000,000
Total	346,568	106.39		—

(1)The ~~370,448~~346,568 total shares for the quarter ended ~~March 31,~~September 30, 2022, consist solely of shares that were withheld by or returned to EOG (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 shares do not count against the November 2021 Authorization (as defined and further discussed below).

(2)Effective November 4, 2021, EOG's Board of Directors (Board) (i) established a new share repurchase authorization to allow for the repurchase by EOG of up to $5 billion of its common stock (November 2021 Authorization). Under the new 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 at the discretion of EOG's management and will depend on a variety of factors, including the then-trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares will be held as treasury shares and will be available for general corporate purposes. The November 2021 Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board at any time. EOG has not repurchased any shares under the November 2021 Authorization as of the date of this filing.

ITEM 4. MINE SAFETY DISCLOSURES

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

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ITEM 5. OTHER INFORMATION

It is currently anticipated that EOG's 2023 annual meeting of stockholders (2023 Annual Meeting) will be held on May 24, 2023, at a time and location to be determined and specified in EOG's proxy statement for the 2023 Annual Meeting.

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

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

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ITEM 6. EXHIBITS


Exhibit No.		Description

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

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

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

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

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

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

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

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

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

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

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

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

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

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

3.2	-	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).

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Exhibit No.		Description

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

10.2	-	EOG Resources, Inc. Amended and Restated Annual Bonus Plan (effective as of January 1, 2022) (Exhibit 10.2 to EOG's Current Report on Form 8-K, filed October 4, 2022) (SEC File No. 001-09743).

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

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

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

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

95	-	Mine Safety Disclosure Exhibit.

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

*101.SCH	-	Inline XBRL Schema Document.

*101.CAL	-	Inline XBRL Calculation Linkbase Document.

*101.DEF	-	Inline XBRL Definition Linkbase Document.

*101.LAB	-	Inline XBRL Label Linkbase Document.

*101.PRE	-	Inline XBRL Presentation Linkbase Document.

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

*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three Months and Nine Months ended ~~March 31,~~September 30, 2022 and 2021, (ii) the Condensed Consolidated Balance Sheets - ~~March 31,~~September 30, 2022 and December 31, 2021, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three Months and Nine Months Ended ~~March 31,~~September 30, 2022 and 2021, (iv) the Condensed Consolidated Statements of Cash Flows - ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022 and 2021 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:	~~May 5,~~November 3, 2022	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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