EOG Resources (EOG) 10-K 23 Feb 23 2022 FY Annual report Financial data

Cover

Cover - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Feb. 16, 2023	Jun. 30, 2022
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-9743
Entity Registrant Name	EOG RESOURCES, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	47-0684736
Entity Address, Address Line One	1111 Bagby
Entity Address, Address Line Two	Sky Lobby 2
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	651-7000
Title of 12(b) Security	Common Stock, par value $0.01 per share
Trading Symbol	EOG
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 64,556
Entity Common Stock, Shares Outstanding		587,723,622
Documents Incorporated by Reference	Documents incorporated by reference. Portions of the Definitive Proxy Statement for the registrant's 2023 Annual Meeting of Stockholders, to be filed within 120 days after December 31, 2022, are incorporated by reference into Part III of this report.
Entity Central Index Key	0000821189
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Amendment Flag	false

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
Auditor Information [Abstract]
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	Houston, Texas
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (LOSS) AND COMPREHENSIVE INCOME (LOSS) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Operating Revenues and Other
Gains (Losses) on Asset Dispositions, Net	$ 74		$ 17		$ (47)
Total	25,702	[1]	18,642	[2]	11,032	[3]
Operating Expenses
Lease and Well	1,331		1,135		1,063
Transportation Costs	966		863		735
Gathering and Processing Costs	621		559		459
Exploration Costs	159		154		146
Dry Hole Costs	45		71		13
Impairments	382		376		2,100
Marketing Costs	6,535		4,173		2,698
Depreciation, Depletion and Amortization	3,542		3,651		3,400
General and Administrative	570		511		484
Taxes Other Than Income	1,585		1,047		478
Total	15,736		12,540		11,576
Operating Income (Loss)	9,966	[4]	6,102	[5]	(544)	[6]
Other Income, Net	114		9		10
Income (Loss) Before Interest Expense and Income Taxes	10,080		6,111		(534)
Interest Expense
Incurred	215		211		236
Capitalized	(36)		(33)		(31)
Net Interest Expense	179		178		205
Income (Loss) Before Income Taxes	9,901		5,933		(739)
Income Tax Provision (Benefit)	2,142		1,269		(134)
Net Income (Loss)	$ 7,759		$ 4,664		$ (605)
Net Income (Loss) Per Share
Basic ( in usd per share)	$ 13.31		$ 8.03		$ (1.04)
Diluted (in usd per share)	$ 13.22		$ 7.99		$ (1.04)
Average Number of Common Shares
Basic (in shares)	583		581		579
Diluted (in shares)	587		584		579
Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	$ 4		$ (1)		$ (7)
Other, Net of Tax	0		1		0
Other Comprehensive Income (Loss)	4		0		(7)
Comprehensive Income (Loss)	7,763		4,664		(612)
Crude Oil and Condensate
Operating Revenues and Other
Revenue from contract with customer	16,367		11,125		5,786
Natural Gas Liquids
Operating Revenues and Other
Revenue from contract with customer	2,648		1,812		668
Natural Gas
Operating Revenues and Other
Revenue from contract with customer	3,781		2,444		837
Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts, Net
Operating Revenues and Other
Revenue not from contract with customer	(3,982)		(1,152)		1,145
Gathering, Processing and Marketing
Operating Revenues and Other
Revenue from contract with customer	6,696		4,288		2,583
Other, Net
Operating Revenues and Other
Revenue not from contract with customer	$ 118		$ 108		$ 60
[1]EOG had sales activity with three significant purchasers in 2022, one totaling $3.3 billion, another totaling $3.1 billion and a third totaling $3.0 billion of consolidated Operating Revenues and Other in the United States segment.[2]EOG had sales activity with two significant purchasers in 2021, one totaling $2.7 billion and the other totaling $2.6 billion of consolidated Operating Revenues and Other in the United States segment.[3]EOG had sales activity with three significant purchasers in 2020, each totaling $1.1 billion of consolidated Operating Revenues and Other in the United States segment.[4]EOG recorded pretax impairment charges of $15 million in 2022 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Note 14.[5]EOG recorded pretax impairment charges of $45 million and dry hole costs of $42 million in 2021 in the Other International segment related to its decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. In addition, EOG recorded net gains of asset dispositions of $58 million in 2021 in the Other International segment during the second quarter of 2021 due to the sale of its China operations. See Notes 14 and 17, respectively.[6]EOG recorded pretax impairment charges of $1,570 million in 2020 for proved oil and gas properties, leasehold costs and other assets due to the decline in commodity prices and revisions of asset retirement obligations for certain properties in the United States segment. In addition, EOG recorded pretax impairment charges of $228 million in 2020 for owned and leased sand and crude-by-rail assets, also in the United States segment. EOG recorded pretax impairment charges of $81 million in 2020 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Notes 13 and 14.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Current Assets
Cash and Cash Equivalents	$ 5,972	$ 5,209
Accounts Receivable, Net	2,774	2,335
Inventories	1,058	584
Income Taxes Receivable	97	0
Other	574	456
Total	10,475	8,584
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	67,322	67,644
Other Property, Plant and Equipment	4,786	4,753
Total Property, Plant and Equipment	72,108	72,397
Less: Accumulated Depreciation, Depletion and Amortization	(42,679)	(43,971)
Total Property, Plant and Equipment, Net	29,429	28,426
Deferred Income Taxes	33	11
Other Assets	1,434	1,215
Total Assets	41,371	38,236
Current Liabilities
Accounts Payable	2,532	2,242
Accrued Taxes Payable	405	518
Dividends Payable	482	436
Liabilities from Price Risk Management Activities	169	269
Current Portion of Long-Term Debt	1,283	37
Current Portion of Operating Lease Liabilities	296	240
Other	346	300
Total	5,513	4,042
Long-Term Debt	3,795	5,072
Other Liabilities	2,574	2,193
Deferred Income Taxes	4,710	4,749
Commitments and Contingencies (Note 8)
Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 588,396,757 Shares and 585,521,512 Shares Issued at December 31, 2022 and 2021, respectively	206	206
Additional Paid in Capital	6,187	6,087
Accumulated Other Comprehensive Loss	(8)	(12)
Retained Earnings	18,472	15,919
Common Stock Held in Treasury, 700,281 Shares and 257,268 Shares at December 31, 2022 and 2021, respectively	(78)	(20)
Total Stockholders' Equity	24,779	22,180
Total Liabilities and Stockholders' Equity	$ 41,371	$ 38,236

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	1,280,000,000	1,280,000,000
Common stock, shares issued (in shares)	588,396,757	585,521,512
Common stock held in treasury (in shares)	700,281	257,268

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	Common Stock	Additional Paid In Capital	Accumulated Other Comprehensive Income (Loss)	Retained Earnings	Common Stock Held In Treasury
Beginning balance at Dec. 31, 2019	$ 21,640	$ 206	$ 5,817	$ (5)	$ 15,649	$ (27)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (Loss) Income	(605)				(605)
Common Stock Issued Under Stock Plans	0		0
Common Stock Dividends Declared	(874)				(874)
Other Comprehensive Income (Loss)	(7)			(7)
Change in Treasury Stock - Stock Compensation Plans, Net	0		(9)			9
Restricted Stock and Restricted Stock Units, Net	0		(9)			9
Stock-Based Compensation Expenses	146		146
Treasury Stock Issued as Compensation	2					2
Ending balance at Dec. 31, 2020	20,302	206	5,945	(12)	14,170	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (Loss) Income	4,664				4,664
Common Stock Issued Under Stock Plans	17		17
Common Stock Dividends Declared	(2,915)				(2,915)
Other Comprehensive Income (Loss)	0			0
Change in Treasury Stock - Stock Compensation Plans, Net	(40)		(22)			(18)
Restricted Stock and Restricted Stock Units, Net	0		(5)			5
Stock-Based Compensation Expenses	152		152
Treasury Stock Issued as Compensation	0					0
Ending balance at Dec. 31, 2021	22,180	206	6,087	(12)	15,919	(20)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (Loss) Income	7,759				7,759
Common Stock Issued Under Stock Plans	24		24
Common Stock Dividends Declared	(5,206)				(5,206)
Other Comprehensive Income (Loss)	4			4
Change in Treasury Stock - Stock Compensation Plans, Net	(116)		(55)			(61)
Restricted Stock and Restricted Stock Units, Net	0		(2)			2
Stock-Based Compensation Expenses	133		133
Treasury Stock Issued as Compensation	1					1
Ending balance at Dec. 31, 2022	$ 24,779	$ 206	$ 6,187	$ (8)	$ 18,472	$ (78)

CONSOLIDATED STATEMENTS OF ST_2

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Common stock dividends declared (in USD per share)	$ 8.875	$ 4.9875	$ 1.50

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cash Flows from Operating Activities
Net Income (Loss)	$ 7,759	$ 4,664	$ (605)
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	3,542	3,651	3,400
Impairments	382	376	2,100
Stock-Based Compensation Expenses	133	152	146
Deferred Income Taxes	(61)	(122)	(186)
(Gains) Losses on Asset Dispositions, Net	(74)	(17)	47
Other, Net	0	13	12
Dry Hole Costs	45	71	13
Mark-to-Market Financial Commodity Derivative Contracts
(Gains) Losses, Net	3,982	1,152	(1,145)
Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts	(3,501)	(638)	1,071
Other, Net	45	7	1
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	(347)	(821)	467
Inventories	(534)	(13)	123
Accounts Payable	90	456	(795)
Accrued Taxes Payable	(113)	312	(49)
Other Assets	(364)	(136)	325
Other Liabilities	(266)	(116)	8
Changes in Components of Working Capital Associated with Investing Activities	375	(200)	75
Net Cash Provided by Operating Activities	11,093	8,791	5,008
Investing Cash Flows
Additions to Oil and Gas Properties	(4,619)	(3,638)	(3,244)
Additions to Other Property, Plant and Equipment	(381)	(212)	(221)
Proceeds from Sales of Assets	349	231	192
Other Investing Activities	(30)	0	0
Changes in Components of Working Capital Associated with Investing Activities	(375)	200	(75)
Net Cash Used in Investing Activities	(5,056)	(3,419)	(3,348)
Financing Cash Flows
Long-Term Debt Borrowings	0	0	1,484
Long-Term Debt Repayments	0	(750)	(1,000)
Dividends Paid	(5,148)	(2,684)	(821)
Treasury Stock Purchased	(118)	(41)	(16)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	28	19	16
Debt Issuance Costs	0	0	(3)
Repayment of Finance Lease Liabilities	(35)	(37)	(19)
Net Cash Used in Financing Activities	(5,273)	(3,493)	(359)
Effect of Exchange Rate Changes on Cash	(1)	1	0
Increase in Cash and Cash Equivalents	763	1,880	1,301
Cash and Cash Equivalents at Beginning of Year	5,209	3,329	2,028
Cash and Cash Equivalents at End of Year	$ 5,972	$ 5,209	$ 3,329

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Nature of Business. EOG Resources, Inc., a Delaware corporation organized in 1985, together with its subsidiaries (collectively, EOG), explores for, develops, produces and markets crude oil, natural gas liquids (NGLs) and natural gas primarily in major producing basins in the United States of America (United States or U.S.) and the Republic of Trinidad and Tobago (Trinidad). EOG is making preparations to drill offshore Australia, as well as evaluating additional exploration, development and exploitation opportunities in these and other select international areas. In addition, EOG is in the process of exiting Block 36 and Block 49 in the Sultanate of Oman (Oman) and is executing an abandonment and reclamation program in Canada. EOG sold its operations in the China Sichuan Basin (China) in the second quarter of 2021. Principles of Consolidation. The consolidated financial statements of EOG include the accounts of all domestic and foreign subsidiaries. Any investments in unconsolidated affiliates, in which EOG is able to exercise significant influence, are accounted for using the equity method. All intercompany accounts and transactions have been eliminated. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (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. Financial Instruments. EOG's financial instruments consist of cash and cash equivalents, financial commodity derivative contracts, accounts receivable, accounts payable and current and long-term debt. The carrying values of cash and cash equivalents, financial commodity derivative contracts, accounts receivable and accounts payable approximate fair value (see Notes 2 and 12). Effective January 1, 2020, EOG adopted the provisions of Accounting Standards Update (ASU) 2016-13, "Measurement of Credit Losses on Financial Instruments" (ASU 2016-13). EOG did not record an impact to retained earnings upon adoption and expects current and future credit losses to be immaterial. EOG continues to monitor the credit risk from third-party companies to determine if expected credit losses may become material. Cash and Cash Equivalents. EOG records as cash equivalents all highly liquid short-term investments with original maturities of three months or less. Oil and Gas Operations. EOG accounts for its crude oil and natural gas exploration and production activities under the successful efforts method of accounting. Oil and gas lease acquisition costs are capitalized when incurred. 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. If the unproved properties are determined to be productive, the appropriate related costs are transferred to proved oil and gas properties. Lease rentals are expensed as incurred. Oil and gas exploration costs, other than the costs of drilling exploratory wells, are expensed as incurred. The costs of drilling exploratory wells are capitalized pending determination of whether EOG has discovered commercial quantities of proved reserves. If commercial quantities of proved reserves are not discovered, such drilling costs are expensed. In some circumstances, it may be uncertain whether commercial quantities of proved reserves have been discovered when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the estimated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made (see Note 16). Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of crude oil and natural gas, are capitalized. Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account. Oil and gas properties are grouped in accordance with the provisions of the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field. Amortization rates are updated quarterly to reflect: 1) the addition of capital costs, 2) reserve revisions (upwards or downwards) and additions, 3) property acquisitions and/or property dispositions and 4) impairments. 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 group. If the expected undiscounted future cash flows, based on EOG's estimate 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 using the Income Approach described in the Fair Value Measurement Topic of the ASC. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value. Other Property, Plant and Equipment . Other property, plant and equipment consists of gathering and processing assets, compressors, buildings and leasehold improvements, computer hardware and software, vehicles, and furniture and fixtures. Other property, plant and equipment is generally depreciated on a straight-line basis over the estimated useful lives of the property, plant and equipment, which range from 3 years to 45 years. Inventories. Inventories consist primarily of tubular goods, materials for completion operations, well equipment and gathering lines held for use in the exploration for, and development and production of, crude oil, NGLs and natural gas reserves. EOG accounts for inventories at the lower of cost and net realizable value with adjustments made, as appropriate, to recognize any reductions in value. Revenue Recognition. EOG presents disaggregated revenues by type of commodity within its Consolidated Statements of Income (Loss) and Comprehensive Income (Loss) and by geographic areas defined as operating segments. See Note 11. Revenues are recognized for the sale of crude oil and condensate, NGLs and natural gas at the point control of the product is transferred to the customer, typically when production is delivered and title or risk of loss transfers to the customer. Arrangements for such sales are evidenced by signed contracts with prices typically based on stated market indices, with certain adjustments for product quality and geographic location. As EOG typically invoices customers shortly after performance obligations have been fulfilled, contract assets and contract liabilities are not recognized. The balances of accounts receivable from contracts with customers as of December 31, 2022 and 2021, were $2,340 million and $2,130 million, respectively, and are included in Accounts Receivable, Net on the Consolidated Balance Sheets. Losses incurred on receivables from contracts with customers are infrequent and have been immaterial. Certain arrangements provide for the sale of fixed quantities of commodities in future years with pricing mechanisms based on future market prices at time of delivery. EOG does not disclose the value of these obligations given the uncertainty of the future realized transaction price. Crude Oil and Condensate. EOG sells its crude oil and condensate production at the wellhead or further downstream at a contractually-specified delivery point. Revenue is recognized when control transfers to the customer based on contract terms which reflect prevailing market prices. Any costs incurred prior to the transfer of control, such as gathering and transportation, are recognized as Operating Expenses. Natural Gas Liquids. EOG delivers certain of its natural gas production to either EOG-owned processing facilities or third-party processing facilities, where extraction of NGLs occurs. For EOG-owned facilities, revenue is recognized after processing upon transfer of NGLs to a customer. For third-party facilities, extracted NGLs are sold to the owner of the processing facility at the tailgate, or EOG takes possession and sells the extracted NGLs at the tailgate or exercises its option to sell further downstream to various customers. Under typical arrangements for third-party facilities, revenue is recognized after processing upon the transfer of control of the NGLs, either at the tailgate of the processing plant or further downstream. EOG recognizes revenues based on contract terms which reflect prevailing market prices, with any costs prior to the transfer of control, such as processing, transportation and fractionation fees, recognized as Transportation Costs and Gathering and Processing Costs, as appropriate. Natural Gas. EOG sells its natural gas production either at the wellhead or further downstream at a contractually-specified delivery point. In connection with the extraction of NGLs, EOG sells residue gas under separate agreements. Typically, EOG takes possession of the natural gas at the tailgate of the processing facility and sells it at the tailgate or further downstream. In each case, EOG recognizes revenues when control transfers to the customer, based on contract terms which reflect prevailing market prices. Gathering, Processing and Marketing. Gathering, processing and marketing revenues represent sales of third-party crude oil and condensate, NGLs and natural gas, as well as fees associated with gathering and processing third-party natural gas and revenues from sales of EOG-owned sand. EOG evaluates whether it is the principal or agent under these transactions. As control of the underlying commodity is transferred to EOG prior to the gathering, processing and marketing activities, EOG considers itself the principal of these arrangements. Accordingly, EOG recognizes these transactions on a gross basis. Purchases of third-party commodities are recorded as Marketing Costs, with sales of third-party commodities and fees received for gathering and processing recorded as Gathering, Processing and Marketing revenues. Capitalized Interest Costs. Interest costs have been capitalized as a part of the historical cost of unproved oil and gas properties. The amount capitalized is an allocation of the interest cost incurred during the reporting period. Capitalized interest is computed only during the exploration and development phases and ceases once production begins. The interest rate used for capitalization purposes is based on the interest rates on EOG's outstanding borrowings. Accounting for Risk Management Activities. Financial commodity derivative instruments are recorded on the balance sheet as either an asset or liability measured at fair value, and changes in the instrument's fair value are recognized currently in earnings unless specific hedge accounting criteria are met. During the three-year period ended December 31, 2022, EOG elected not to designate any of its financial commodity derivative instruments as accounting hedges and, accordingly, changes in the fair value of these outstanding derivative instruments are recognized as gains or losses in the period of change. The gains or losses are recorded as Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts on the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss). The related cash flow impact of settled contracts is reflected as cash flows from operating activities. EOG employs net presentation of financial commodity derivative assets and liabilities for financial reporting purposes when such assets and liabilities are with the same counterparty and subject to a master netting arrangement. See Note 12. Income Taxes. Income taxes are accounted for using the asset and liability approach. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis. EOG assesses the realizability of deferred tax assets and recognizes valuation allowances as appropriate. See Note 6. Effective January 1, 2021, EOG adopted the provisions of ASU 2019-12, "Income Taxes (Topic 740) Simplifying the Accounting for Income Taxes" (ASU 2019-12). There was no impact upon adoption of ASU 2019-12 to EOG's consolidated financial statements or related disclosures. Foreign Currency Translation. The United States dollar is the functional currency for all of EOG's consolidated subsidiaries except for its Canadian subsidiaries, for which the functional currency is the Canadian dollar. For subsidiaries whose functional currency is deemed to be other than the United States dollar, asset and liability accounts are translated at year-end exchange rates and revenues and expenses are translated at average exchange rates prevailing during the year. Translation adjustments are included in Accumulated Other Comprehensive Loss on the Consolidated Balance Sheets. Any gains or losses on transactions or monetary assets or liabilities in currencies other than the functional currency are included in net income (loss) in the current period. See Note 4. Net Income (Loss) Per Share. Basic net income (loss) per share is computed on the basis of the weighted-average number of common shares outstanding during the period. Diluted net income (loss) per share is computed based upon the weighted-average number of common shares outstanding during the period plus the assumed issuance of common shares for all potentially dilutive securities. See Note 9. Stock-Based Compensation . EOG measures the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award. See Note 7. Leases. In the ordinary course of business, EOG enters into contracts for drilling, fracturing, compression, real estate and other services which contain equipment and other assets and that meet the definition of a lease under ASC "Leases (Topic 842)." The lease term for these contracts, which includes any renewals at EOG's option that are reasonably certain to be exercised, ranges from one month to 30 years. Right of Use (ROU) assets and related liabilities are recognized on the commencement date on the Consolidated Balance Sheets based on future lease payments, discounted based on the rate implicit in the contract, if readily determinable, or EOG's incremental borrowing rate commensurate with the lease term of the contract. EOG estimates its incremental borrowing rate based on the approximate rate required to borrow on a collateralized basis. Contracts with lease terms of less than 12 months are not recorded on the Consolidated Balance Sheets, but instead are disclosed as short-term lease cost. EOG has elected not to separate non-lease components from all leases, excluding those for fracturing services, real estate and produced water disposal, as lease payments under these contracts contain significant non-lease components, such as labor and operating costs. See Note 18. Recently Issued Accounting Standards. In March 2020, the FASB issued 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.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-Term Debt at December 31, 2022 and 2021 consisted of the following (in millions): 2022 2021 2.625% Senior Notes due 2023 $ 1,250 $ 1,250 3.15% Senior Notes due 2025 500 500 4.15% Senior Notes due 2026 750 750 6.65% Senior Notes due 2028 140 140 4.375% Senior Notes due 2030 750 750 3.90% Senior Notes due 2035 500 500 5.10% Senior Notes due 2036 250 250 4.950% Senior Notes due 2050 750 750 Long-Term Debt 4,890 4,890 Finance Leases (see Note 18) 215 250 Less: Current Portion of Long-Term Debt 1,283 37 Unamortized Debt Discount 23 27 Debt Issuance Costs 4 4 Total Long-Term Debt $ 3,795 $ 5,072 The senior notes in the table above are senior, unsecured obligations that rank equally in right of payment with all of our other unsecured and unsubordinated outstanding debt. At December 31, 2022, the aggregate annual maturities of current and long-term debt (excluding finance lease obligations) were $1.25 billion in 2023, zero in 2024, $500 million in 2025, $750 million in 2026 and zero in 2027. At December 31, 2022 and 2021, EOG had no outstanding commercial paper borrowings and did not utilize any commercial paper borrowings during 2022 or 2021. On February 1, 2021, EOG repaid upon maturity the $750 million aggregate principal amount of its 4.100% Senior Notes due 2021. EOG currently has a $2.0 billion senior unsecured Revolving Credit Agreement (the 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 the 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 December 31, 2022, EOG was in compliance with this financial covenant. At December 31, 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 December 31, 2022, would have been 5.29% and 7.50%, respectively.

Stockholder's Equity

Stockholder's Equity	12 Months Ended
	Dec. 31, 2022
Stockholders' Equity Note [Abstract]
Stockholder's Equity	Stockholders' Equity Common Stock. In September 2001, EOG's Board of Directors (Board) authorized the repurchase of an aggregate maximum of 10 million shares of common stock that superseded all previous authorizations (September 2001 Authorization). EOG last repurchased shares under the September 2001 Authorization in March 2003. Effective November 4, 2021, the Board (i) established a new share repurchase authorization to allow for the repurchase by EOG of up to $5 billion of common stock (November 2021 Authorization) and (ii) revoked and terminated the September 2001 Authorization. EOG has not repurchased any shares under the November 2021 Authorization and, accordingly, $5 billion remained available for purchase under the November 2021 Authorization as of December 31, 2022. Shares of common stock are from time to time withheld by, or returned to, EOG in satisfaction of tax withholding obligations arising upon the exercise of employee stock options or stock-settled stock appreciation rights (SARs), the vesting of restricted stock, restricted stock unit or performance unit grants or in payment of the exercise price of employee stock options. Such shares withheld or returned prior to November 4, 2021 did not count against the September 2001 Authorization, and such shares withheld or returned on or subsequent to November 4, 2021 have not counted, and will not count, against the November 2021 Authorization. Shares purchased, withheld and returned are held in treasury for, among other purposes, fulfilling any obligations arising under EOG's stock-based compensation plans and any other approved transactions or activities for which such shares of common stock may be required. On February 23, 2023, the Board declared a quarterly cash dividend on the common stock of $0.825 per share to be paid on April 28, 2023, to stockholders of record as of April 14, 2023. The Board also declared on such date a special dividend on the common stock of $1.00 per share to be paid on March 30, 2023, to stockholders of record as of March 16, 2023. 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 paid 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, paid on December 30, 2022, to stockholders of record as of December 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. On August 4, 2022, the Board declared a special cash 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 May 5, 2022, the Board declared a quarterly cash dividend on the common stock of $0.75 per share paid on July 29, 2022, to stockholders of record as of July 15, 2022. The Board also declared on such date a special dividend on the common stock of $1.80 per share paid on June 30, 2022, to stockholders of record as of June 15, 2022. 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 on the common stock of $1.00 per share paid on March 29, 2022, to stockholders of record as of March 15, 2022. On November 4, 2021, the Board (i) increased the quarterly cash dividend on the common stock from the previous $0.4125 per share to $0.75 per share, effective beginning with the dividend paid on January 28, 2022, to stockholders of record as of January 14, 2022, and (ii) declared a special cash dividend on the common stock of $2.00 per share, paid on December 30, 2021, to stockholders of record as of December 15, 2021. On May 6, 2021, the Board declared a special cash dividend on the common stock of $1.00 per share. The special cash dividend was paid on July 30, 2021, to stockholders of record as of July 16, 2021 (and was in addition to the quarterly cash dividend on the common stock of $0.4125 per share also paid on July 30, 2021, to stockholders of record as of July 16, 2021). On February 25, 2021, the Board increased the quarterly cash dividend on the common stock from the previous $0.375 per share to $0.4125 per share, effective beginning with the dividend to be paid on April 30, 2021, to stockholders of record as of April 16, 2021. On February 27, 2020, the Board increased the quarterly cash dividend on the common stock from the previous $0.2875 per share to $0.375 per share, effective beginning with the dividend to be paid on April 30, 2020, to stockholders of record as of April 16, 2020. The following summarizes Common Stock activity for each of the years ended December 31, 2022, 2021 and 2020 (in thousands): Common Shares Issued Treasury Outstanding Balance at December 31, 2019 582,213 (299) 581,914 Common Stock Issued Under Stock-Based Compensation Plans 1,482 — 1,482 Treasury Stock Purchased (1) — (389) (389) Common Stock Issued Under Employee Stock Purchase Plan — 377 377 Treasury Stock Issued Under Stock-Based Compensation Plans — 187 187 Balance at December 31, 2020 583,695 (124) 583,571 Common Stock Issued Under Stock-Based Compensation Plans 1,511 — 1,511 Treasury Stock Purchased (1) — (504) (504) Common Stock Issued Under Employee Stock Purchase Plan 316 — 316 Treasury Stock Issued Under Stock-Based Compensation Plans — 371 371 Balance at December 31, 2021 585,522 (257) 585,265 Common Stock Issued Under Stock-Based Compensation Plans 2,674 — 2,674 Treasury Stock Purchased (1) — (997) (997) Common Stock Issued Under Employee Stock Purchase Plan 201 — 201 Treasury Stock Issued Under Stock-Based Compensation Plans — 554 554 Balance at December 31, 2022 588,397 (700) 587,697 (1) Represents 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 SARs 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. Preferred Stock . EOG currently has one authorized series of preferred stock. As of December 31, 2022, there were no shares of preferred stock outstanding.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss) Accumulated other comprehensive income (loss) includes certain transactions that have been reported in the Consolidated Statements of Stockholders' Equity. The components of Accumulated Other Comprehensive Loss at December 31, 2022 and 2021 consisted of the following (in millions): Foreign Currency Translation Adjustment Other Total December 31, 2020 $ (10) $ (2) $ (12) Other comprehensive income (loss) before taxes (1) 1 — Tax effects — — — Other comprehensive loss (1) 1 — December 31, 2021 (11) (1) (12) Other comprehensive income (loss) before taxes 4 — 4 Tax effects — — — Other comprehensive income (loss) 4 — 4 December 31, 2022 $ (7) $ (1) $ (8) No significant amount was reclassified out of Accumulated Other Comprehensive Income (Loss) during the years ended December 31, 2022, 2021 and 2020.

Other Income, Net

Other Income, Net	12 Months Ended
	Dec. 31, 2022
Other Income and Expenses [Abstract]
Other Income, Net	Other Income, NetOther income, net for 2022 included interest income ($85 million) and equity income from investments in ammonia plants in Trinidad ($46 million), partially offset by an upward adjustment to deferred compensation expense ($15 million). Other income, net for 2021 included equity income from investments in ammonia plants in Trinidad ($18 million) and interest income ($3 million), partially offset by an upward adjustment to deferred compensation expense ($13 million). Other income, net for 2020 included interest income ($12 million), partially offset by equity losses from investments in ammonia plants in Trinidad ($2 million).

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The principal components of EOG's total net deferred income tax liabilities at December 31, 2022 and 2021 were as follows (in millions): 2022 2021 Deferred Income Tax Assets (Liabilities) Foreign Oil and Gas Exploration and Development Costs Deducted for Tax Under Book Depreciation, Depletion and Amortization $ (18) $ (19) Foreign Asset Retirement Obligations 81 51 Foreign Accrued Expenses and Liabilities 13 15 Foreign Net Operating Loss 82 80 Foreign Valuation Allowances (116) (111) Foreign Other (9) (5) Total Net Deferred Income Tax Assets $ 33 $ 11 Deferred Income Tax (Assets) Liabilities Oil and Gas Exploration and Development Costs Deducted for Tax Over Book Depreciation, Depletion and Amortization $ 5,291 $ 5,063 Financial Commodity Derivative Contracts (421) (97) Deferred Compensation Plans (58) (57) Equity Awards (60) (86) Other (42) (74) Total Net Deferred Income Tax Liabilities $ 4,710 $ 4,749 Total Net Deferred Income Tax Liabilities $ 4,677 $ 4,738 The components of Income (Loss) Before Income Taxes for the years indicated below were as follows (in millions): 2022 2021 2020 United States $ 9,752 $ 5,787 $ (756) Foreign 149 146 17 Total $ 9,901 $ 5,933 $ (739) The principal components of EOG's Income Tax Provision (Benefit) for the years indicated below were as follows (in millions): 2022 2021 2020 Current: Federal $ 2,020 $ 1,203 $ (108) State 126 85 7 Foreign 62 105 40 Total 2,208 1,393 (61) Deferred: Federal (2) (41) (153) State (37) (62) (15) Foreign (22) (19) (18) Total (61) (122) (186) Other Non-Current: (1) Federal — — 113 Foreign (5) (2) — Total (5) (2) 113 Income Tax Provision (Benefit) $ 2,142 $ 1,269 $ (134) (1) Includes changes in certain amounts that are expected to be paid or received beyond the next twelve months. The primary component in 2020 is refundable alternative minimum tax (AMT) credits. The differences between taxes computed at the U.S. federal statutory tax rate and EOG's effective rate for the years indicated below were as follows: 2022 2021 2020 Statutory Federal Income Tax Rate 21.0 % 21.0 % 21.0 % State Income Tax, Net of Federal Benefit 0.7 0.3 0.9 Income Tax Provision Related to Foreign Operations — 0.9 (0.1) Income Tax Provision Related to Canadian Operations — — (2.4) Stock-Based Compensation — 0.2 (2.9) Other — (1.0) 1.7 Effective Income Tax Rate 21.7 % 21.4 % 18.2 % Deferred tax assets are recorded for future deductible amounts and certain other tax benefits, such as tax net operating losses (NOLs) and tax credit carryforwards, provided that management assesses the utilization of such assets to be "more likely than not." Management assesses the available positive and negative evidence to estimate if sufficient future taxable income will be generated to use the existing deferred tax assets. On the basis of this evaluation, EOG has recorded valuation allowances for the portion of certain foreign and state deferred tax assets that management does not believe are more likely than not to be realized. The principal components of EOG's rollforward of valuation allowances for deferred income tax assets for the years indicated below were as follows (in millions): 2022 2021 2020 Beginning Balance $ 219 $ 219 $ 201 Increase (1) 27 15 25 Decrease (2) (33) (14) (11) Other (3) (6) (1) 4 Ending Balance $ 207 $ 219 $ 219 (1) Increase in valuation allowance related to the generation of tax NOLs and other deferred tax assets. (2) Decrease in valuation allowance associated with adjustments to certain deferred tax assets and their related allowances. (3) Represents dispositions, revisions and/or foreign exchange rate variances and the effect of statutory income tax rate changes. As of December 31, 2022, EOG had state income tax NOLs of approximately $2.2 billion. Certain state NOLs have an indefinite carryforward and all others expire between 2023 and 2040. EOG also has Canadian NOLs of $300 million, some of which can be carried forward up to 20 years. As described previously, these NOLs and other less significant tax benefits have been evaluated for the likelihood of utilization, and valuation allowances have been established for the portion of these deferred income tax assets that do not meet the "more likely than not" threshold. As of December 31, 2022, EOG did not have material amounts of unrecognized tax benefits. Additionally, no interest or penalties have been recognized in the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss). EOG does not expect its unrecognized tax benefits to change significantly in the next twelve months. EOG and its subsidiaries file income tax returns and are subject to tax audits in the U.S. and various state, local and foreign jurisdictions. EOG's earliest open tax years in its principal jurisdictions are as follows: U.S. federal (2019), Canada (2018), Trinidad (2015), Oman (2020) and Australia (2021). EOG's foreign subsidiaries' undistributed earnings are not considered to be permanently reinvested outside of the U.S. and deferred income taxes have been accrued on any such outside basis differences. Additionally, EOG’s foreign earnings may be subject to the U.S. federal "global intangible low-taxed income" (GILTI) inclusion. EOG records any GILTI tax as a period expense. On August 16, 2022, the U.S. President signed into law the Inflation Reduction Act of 2022, which contains, among other provisions, certain tax provisions as well as a variety of climate and energy incentives. While there was no immediate income tax impact upon enactment, in the future, EOG may become subject to the new corporate alternative minimum tax or other provisions, such as the excise tax on stock buybacks. Additionally, as part of EOG's strategy to reduce GHG emissions, EOG may become eligible for certain new or enhanced income tax credits attributable to these efforts.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2022
Share-Based Payment Arrangement [Abstract]
Employee Benefit Plans	Employee Benefit Plans Stock-Based Compensation During 2022, EOG maintained various stock-based compensation plans as discussed below. EOG recognizes compensation expense on grants of stock options, SARs, restricted stock, restricted stock units and performance units and grants made under the EOG Resources, Inc. Employee Stock Purchase Plan (ESPP). Stock-based compensation expense is calculated based upon the grant date estimated fair value of the awards, net of forfeitures, based upon EOG's historical employee turnover rate. Compensation expense is amortized over the shorter of the vesting period or the period from date of grant until the date the employee becomes eligible to retire without company approval. Stock-based compensation expense is included on the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss) based upon the job functions of the employees receiving the grants. Compensation expense related to EOG's stock-based compensation plans for the years ended December 31, 2022, 2021 and 2020 was as follows (in millions): 2022 2021 2020 Lease and Well $ 40 $ 49 $ 52 Gathering and Processing Costs 4 3 1 Exploration Costs 15 20 21 General and Administrative 74 80 72 Total $ 133 $ 152 $ 146 The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provided for grants of stock options, 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 were subject to outstanding awards under the 2008 Plan as of April 29, 2021, that are subsequently canceled or 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). The vesting schedules for grants of stock options, SARs, restricted stock and restricted stock units, and Performance Units are generally as follows: Grant Type Vesting Schedule Stock Options/SARs Vesting in increments of one-third on each of the first three anniversaries, respectively, of the date of grant Restricted Stock/Restricted Stock Units "Cliff" vesting three years from the date of grant Performance Units "Cliff" vesting on the February 28th following the three At December 31, 2022, approximately 16 million common shares remained available for grant under the 2021 Plan. EOG's policy is to issue shares related to the 2021 Plan from previously authorized unissued shares or treasury shares to the extent treasury shares are available. During 2022, 2021 and 2020, EOG issued shares in connection with stock option/SAR exercises, restricted stock grants, restricted stock unit and Performance Unit releases and ESPP purchases. Excess net tax benefits / (deficiencies) recognized within the income tax provision were $22 million, $(11) million and $(22) million for the years ended December 31, 2022, 2021 and 2020, respectively. Stock Options and Stock-Settled Stock Appreciation Rights and Employee Stock Purchase Plan. Participants in EOG's stock-based compensation plans (including the 2008 Plan and 2021 Plan) have been or may be granted options to purchase shares of Common Stock. In addition, participants in EOG's stock-based compensation plans (including the 2008 Plan and 2021 Plan) have been or may be granted SARs, representing the right to receive shares of Common Stock based on the appreciation in the stock price from the date of grant on the number of SARs granted. Stock options and SARs are granted at a price not less than the market price of the Common Stock on the date of grant. Terms for stock options and SARs granted have generally not exceeded a maximum term of seven years. EOG's ESPP allows eligible employees to semi-annually purchase, through payroll deductions, shares of Common Stock at 85 percent of the fair market value at specified dates. Contributions to the ESPP are limited to 10 percent of the employee's pay (subject to certain ESPP limits) during each of the two six-month offering periods each year. 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 ESPP grants is estimated using the Black-Scholes-Merton model. Stock-based compensation expense related to stock option, SAR and ESPP grants totaled $34 million, $48 million and $62 million for the years ended December 31, 2022, 2021 and 2020, respectively. Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants for the years ended December 31, 2022, 2021 and 2020 were as follows: Stock Options/SARs ESPP 2022 2021 2020 2022 2021 2020 Weighted Average Fair Value of Grants $ 28.30 $ 24.92 $ 11.06 $ 26.62 $ 18.12 $ 19.14 Expected Volatility 42.20 % 42.24 % 44.47 % 43.00 % 51.27 % 53.48 % Risk-Free Interest Rate 0.89 % 0.50 % 0.21 % 1.30 % 0.07 % 0.90 % Dividend Yield 3.28 % 2.26 % 3.27 % 2.89 % 2.89 % 2.27 % Expected Life 5.3 years 5.2 years 5.2 years 0.5 years 0.5 years 0.5 years 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 the stock option and SAR transactions for the years ended December 31, 2022, 2021 and 2020 (stock options and SARs in thousands): 2022 2021 2020 Number Weighted Number Weighted Number Weighted Outstanding at January 1 9,969 $ 84.37 10,186 $ 84.08 9,395 $ 94.53 Granted 2 97.64 1,982 81.68 1,996 37.63 Exercised (1) (5,526) 89.70 (1,130) 63.98 (23) 69.59 Forfeited (220) 82.74 (1,069) 98.15 (1,182) 88.93 Outstanding at December 31 4,225 77.49 9,969 84.37 10,186 84.08 Stock Options/SARs Exercisable at December 31 2,462 84.53 6,197 95.33 6,343 96.41 (1) The total intrinsic value of stock options/SARs exercised during the years 2022, 2021 and 2020 was $190 million, $27 million and $0.4 million, respectively. The intrinsic value is based upon the difference between the market price of the Common Stock on the date of exercise and the grant price of the stock options/SARs. At December 31, 2022, there were 4.1 million stock options/SARs vested or expected to vest with a weighted average grant price of $77.85 per share, an intrinsic value of $211 million and a weighted average remaining contractual life of 4.1 years. The following table summarizes certain information for the stock options and SARs outstanding and exercisable at December 31, 2022 (stock options and SARs in thousands): Stock Options/SARs Outstanding Stock Options/SARs Exercisable Range of Stock Weighted Weighted Aggregate Intrinsic Value (1) Stock Weighted Weighted Aggregate Intrinsic Value (1) $ 34.00 to $ 52.99 1,029 4 $ 37.52 466 4 $ 37.51 53.00 to 80.99 593 3 74.98 584 3 75.04 81.00 to 81.99 1,513 6 81.81 331 5 81.81 82.00 to 96.99 562 1 95.62 553 1 95.75 97.00 to 129.99 528 3 126.51 528 3 126.53 4,225 4 77.49 $ 220 2,462 3 84.53 $ 111 (1) Based upon the difference between the closing market price of the Common Stock on the last trading day of the year and the grant price of in-the-money stock options and SARs, in millions. At December 31, 2022, unrecognized compensation expense related to non-vested stock option and SAR grants totaled $31 million. This unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.4 years. At the 2018 Annual Meeting of Stockholders, EOG stockholders approved an amendment and restatement of the ESPP to (among other changes) increase the number of shares available for grant. At December 31, 2022, approximately 1.4 million shares of Common Stock remained available for grant under the ESPP. The following table summarizes ESPP activity for the years ended December 31, 2022, 2021 and 2020 (in thousands, except number of participants): 2022 2021 2020 Approximate Number of Participants 1,969 2,036 2,063 Shares Purchased 201 316 377 Aggregate Purchase Price $ 17,250 $ 17,224 $ 16,103 Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Upon vesting of restricted stock, shares of Common Stock are released to the employee. Upon vesting, restricted stock units are converted into shares of Common Stock and released to the employee. Stock-based compensation expense related to restricted stock and restricted stock units totaled $88 million, $89 million and $75 million for the years ended December 31, 2022, 2021 and 2020, respectively. The following table sets forth the restricted stock and restricted stock unit transactions for the years ended December 31, 2022, 2021 and 2020 (shares and units in thousands): 2022 2021 2020 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 4,680 $ 69.37 4,742 $ 74.97 4,546 $ 90.16 Granted 1,637 113.21 1,422 81.50 1,488 38.10 Released (1) (2,019) 81.76 (1,388) 101.00 (1,213) 85.92 Forfeited (185) 68.89 (96) 68.26 (79) 86.52 Outstanding at December 31 (2) 4,113 80.77 4,680 69.37 4,742 74.97 (1) (1) The total intrinsic value of restricted stock and restricted stock units released during the years ended December 31, 2022, 2021 and 2020 was $223 million, $110 million and $48 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date restricted stock and restricted stock units are released. (2) (2) The total intrinsic value of restricted stock and restricted stock units outstanding at December 31, 2022, 2021 and 2020 was $533 million, $416 million and $236 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year. At December 31, 2022, unrecognized compensation expense related to restricted stock and restricted stock units totaled $285 million. Such unrecognized expense will be recognized on a straight-line basis over a weighted average period of 1.8 years. Performance Units. EOG has granted Performance Units to its executive officers annually since 2012. For the grants made prior to September 2022, as more fully discussed in the grant agreements, the applicable performance metric is EOG's total shareholder return (TSR) over a three-year performance period relative to the TSR over the same period of a designated group of peer companies. Upon the application of the applicable performance multiple at the completion of the three-year performance period, a minimum of 0% and a maximum of 200% of the Performance Units granted could be outstanding. For the grants made beginning in September 2022, as more fully discussed in the grant agreements, the applicable performance metrics are 1) EOG's TSR over a three-year performance period relative to the TSR over the same period of a designated group of peer companies and 2) EOG's average return on capital employed (ROCE) over the three-year performance period. At the end of the three-year performance period, a performance multiple based on EOGs 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 $11 million, $15 million and $9 million for the years ended December 31, 2022, 2021 and 2020, respectively. Weighted average fair values and valuation assumptions used to value Performance Units during the years ended December 31, 2022, 2021 and 2020 were as follows: 2022 2021 2020 Weighted Average Fair Value of Grants $ 126.55 $ 95.16 $ 42.77 Expected Volatility 56.11 % 53.80 % 47.27 % Risk-Free Interest Rate 4.01 % 0.59 % 0.16 % Expected volatility is based on the term-matched historical volatility over the simulated term, which is calculated as the time between the grant date and the end of the performance period. The risk-free interest rate is derived from the Treasury Constant Maturities yield curve on the grant date. The following table sets forth the Performance Unit transactions for the years ended December 31, 2022, 2021 and 2020 (units in thousands): 2022 2021 2020 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 1 679 $ 84.97 613 $ 88.38 598 $ 103.91 Granted 122 126.55 222 95.16 172 42.77 Granted for Performance Multiple (1) — — 19 113.81 66 119.10 Released (2) (57) 136.74 (175) 113.06 (223) 103.87 Forfeited for Performance Multiple (3) (56) 136.74 — — — — Outstanding at December 31 (4) 688 (5) 83.82 679 84.97 613 88.38 (1) Upon completion of the performance period for the Performance Units granted in 2017 and 2016, a performance multiple of 125% and 150%, respectively, was applied to each of the grants resulting in additional grants of Performance Units in February 2021 and 2020. (2) The total intrinsic value of Performance Units released during the years ended December 31, 2022, 2021 and 2020 was $7 million, $13 million and $13 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date 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 December 31, 2022, 2021 and 2020 was $89 million, $60 million and $31 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year. (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 1,376 Performance Units could be outstanding. At December 31, 2022, unrecognized compensation expense related to Performance Units totaled $18 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.8 years. Upon completion of the performance period for the Performance Units granted in September 2019, a performance multiple of 50% was applied to the grants resulting in a forfeiture of 86,076 Performance Units in February 2023. 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 plan were $56 million, $52 million and $46 million for 2022, 2021 and 2020, respectively. In addition, EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan. These pension plans are available to most employees of the Trinidadian subsidiary. EOG's combined contributions to these plans were $1 million, for each of 2022, 2021 and 2020, respectively. For the Trinidadian defined benefit pension plan, the benefit obligation, fair value of plan assets and (prepaid)/accrued benefit cost totaled $14 million, $15 million and $(0.5) million, respectively, at December 31, 2022, and $13 million, $14 million and $(0.1) million, respectively, at December 31, 2021. 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.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Letters of Credit and Guarantees. At December 31, 2022 and 2021, respectively, EOG had standby letters of credit and guarantees outstanding totaling approximately $776 million and $831 million, primarily representing guarantees of payment or performance obligations on behalf of subsidiaries. As of February 16, 2023, EOG had received no demands for payment under these guarantees. Minimum Commitments. At December 31, 2022, total minimum commitments from purchase and service obligations and transportation and storage service commitments not qualifying as leases, based on current transportation and storage rates and the foreign currency exchange rates used to convert Canadian dollars into United States dollars at December 31, 2022, were as follows (in millions): Total Minimum 2023 $ 1,362 2024 1,149 2025 984 2026 791 2027 642 2028 and beyond 1,570 $ 6,498 Delivery Commitments. EOG sells crude oil and natural gas from its producing operations under a variety of contractual arrangements. At December 31, 2022, EOG was committed to deliver to multiple parties fixed quantities of crude oil of 7 million barrels (MMBbls) in 2023, 7 MMBbls in 2024 and 1 MMBbls in 2025. Additionally at December 31, 2022, EOG was committed to deliver to multiple parties fixed quantities of natural gas of 347 billion cubic feet (Bcf) in 2023, 321 Bcf in 2024, 277 Bcf in 2025, 297 Bcf in 2026, 293 Bcf in 2027 and 3,540 Bcf thereafter. All delivery commitments are expected to be sourced from future production of available reserves. 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.

Net Income (Loss) Per Share

Net Income (Loss) Per Share	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Net Income (Loss) Per Share	Net Income (Loss) Per Share The following table sets forth the computation of Net Income (Loss) Per Share for the years ended December 31, 2022, 2021 and 2020 (in millions, except per share data): 2022 2021 2020 Numerator for Basic and Diluted Earnings per Share - Net Income (Loss) $ 7,759 $ 4,664 $ (605) Denominator for Basic Earnings per Share - Weighted Average Shares 583 581 579 Potential Dilutive Common Shares - Stock Options/SARs 2 — — Restricted Stock/Units and Performance Units 2 3 — Denominator for Diluted Earnings per Share - Adjusted Diluted Weighted Average Shares 587 584 579 Net Income (Loss) Per Share Basic $ 13.31 $ 8.03 $ (1.04) Diluted $ 13.22 $ 7.99 $ (1.04) The diluted earnings per share calculation excludes stock option, SAR, restricted stock, restricted stock unit, Performance Unit and ESPP grants that were anti-dilutive. Shares underlying the excluded stock option, SAR and ESPP grants were 1 million, 6 million and 10 million for the years ended December 31, 2022, 2021 and 2020, respectively. For the year ended December 31, 2020, 5 million shares underlying grants of restricted stock, restricted stock units and Performance Units were excluded.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2022
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Net cash paid for (received from) interest and income taxes was as follows for the years ended December 31, 2022, 2021 and 2020 (in millions): 2022 2021 2020 Interest, Net of Capitalized Interest $ 173 $ 185 $ 205 Income Taxes, Net of Refunds Received $ 2,475 $ 1,114 $ (206) EOG's accrued capital expenditures at December 31, 2022, 2021 and 2020 were $713 million, $592 million and $414 million, respectively. Non-cash investing activities for the year ended December 31, 2022, included additions of $153 million to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the year ended December 31, 2021, included additions of $50 million to EOG's oil and gas properties as a result of property exchanges and an addition of $74 million to EOG's other property, plant and equipment made in connection with finance lease transactions for storage facilities. Non-cash investing activities for the year ended December 31, 2020, included additions of $212 million to EOG's oil and gas properties as a result of property exchanges and an addition of $174 million to EOG's other property, plant and equipment made in connection with finance lease transactions for storage facilities. Cash paid for leases for the years ended December 31, 2022, 2021 and 2020, is disclosed in Note 18.

Business Segment Information

Business Segment Information	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Business Segment Information	Business Segment InformationEOG's operations are all crude oil, NGLs and natural gas exploration and production-related. The Segment Reporting Topic of the ASC establishes standards for reporting information about operating segments in annual financial statements. Operating segments are defined as components of an enterprise about which separate financial information is available and evaluated regularly by the chief operating decision maker, or decision-making group, in deciding how to allocate resources and in assessing performance. EOG's chief operating decision-making process is informal and involves the Chairman of the Board and Chief Executive Officer and other key officers. This group routinely reviews and makes operating decisions related to significant issues associated with each of EOG's major producing areas (including in the United States and in Trinidad) and its exploration programs both inside and outside the United States. For segment reporting purposes, the chief operating decision makers consider the major United States producing areas to be one operating segment. Financial information by reportable segment is presented below as of and for the years ended December 31, 2022, 2021 and 2020 (in millions): United Trinidad Other International (1) Total 2022 Crude Oil and Condensate $ 16,349 $ 18 $ — $ 16,367 Natural Gas Liquids 2,648 — — 2,648 Natural Gas 3,489 292 — 3,781 Losses on Mark-to-Market Financial Commodity Derivative Contracts, Net (3,982) — — (3,982) Gathering, Processing and Marketing 6,695 1 — 6,696 Gains (Losses) on Asset Dispositions, Net 77 (4) 1 74 Other, Net 118 — — 118 Operating Revenues and Other (2) 25,394 307 1 25,702 Depreciation, Depletion and Amortization 3,469 73 — 3,542 Operating Income (Loss) (3) 9,880 122 (36) 9,966 Interest Income 81 2 2 85 Other Income (Expense) (17) 46 — 29 Net Interest Expense 179 — — 179 Income (Loss) Before Income Taxes 9,765 170 (34) 9,901 Income Tax Provision 2,106 35 1 2,142 Additions to Oil and Gas Properties, Excluding Dry Hole Costs 4,599 122 6 4,727 Total Property, Plant and Equipment, Net 29,109 307 13 29,429 Total Assets 40,349 879 143 41,371 2021 Crude Oil and Condensate $ 11,094 $ 31 $ — $ 11,125 Natural Gas Liquids 1,812 — — 1,812 Natural Gas 2,156 270 18 2,444 Losses on Mark-to-Market Financial Commodity Derivative Contracts, Net (1,152) — — (1,152) Gathering, Processing and Marketing 4,287 1 — 4,288 Gains (Losses) on Asset Dispositions, Net (40) (2) 59 17 Other, Net 108 — — 108 Operating Revenues and Other (4) 18,265 300 77 18,642 Depreciation, Depletion and Amortization 3,558 87 6 3,651 Operating Income (Loss) (5) 6,013 151 (62) 6,102 Interest Income 3 — — 3 Other Income (Expense) (14) 8 12 6 Net Interest Expense 178 — — 178 Income (Loss) Before Income Taxes 5,824 159 (50) 5,933 Income Tax Provision (Benefit) 1,247 66 (44) 1,269 Additions to Oil and Gas Properties, Excluding Dry Hole Costs 3,557 55 5 3,617 Total Property, Plant and Equipment, Net 28,213 204 9 28,426 Total Assets 37,436 637 163 38,236 United Trinidad Other International (1) Total 2020 Crude Oil and Condensate $ 5,774 $ 11 $ 1 $ 5,786 Natural Gas Liquids 668 — — 668 Natural Gas 614 169 54 837 Gains on Mark-to-Market Financial Commodity Derivative Contracts, Net 1,145 — — 1,145 Gathering, Processing and Marketing 2,581 2 — 2,583 Losses on Asset Dispositions, Net (47) — — (47) Other, Net 60 — — 60 Operating Revenues and Other (6) 10,795 182 55 11,032 Depreciation, Depletion and Amortization 3,324 60 16 3,400 Operating Income (Loss) (7) (546) 75 (73) (544) Interest Income 11 1 — 12 Other Expense — (2) — (2) Net Interest Expense 205 — — 205 Income (Loss) Before Income Taxes (740) 74 (73) (739) Income Tax Provision (Benefit) (157) 15 8 (134) (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 had sales activity with three significant purchasers in 2022, one totaling $3.3 billion, another totaling $3.1 billion and a third totaling $3.0 billion of consolidated Operating Revenues and Other in the United States segment. (3) EOG recorded pretax impairment charges of $15 million in 2022 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Note 14. (4) EOG had sales activity with two significant purchasers in 2021, one totaling $2.7 billion and the other totaling $2.6 billion of consolidated Operating Revenues and Other in the United States segment. (5) EOG recorded pretax impairment charges of $45 million and dry hole costs of $42 million in 2021 in the Other International segment related to its decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. In addition, EOG recorded net gains of asset dispositions of $58 million in 2021 in the Other International segment during the second quarter of 2021 due to the sale of its China operations. See Notes 14 and 17, respectively. (6) EOG had sales activity with three significant purchasers in 2020, each totaling $1.1 billion of consolidated Operating Revenues and Other in the United States segment. (7) EOG recorded pretax impairment charges of $1,570 million in 2020 for proved oil and gas properties, leasehold costs and other assets due to the decline in commodity prices and revisions of asset retirement obligations for certain properties in the United States segment. In addition, EOG recorded pretax impairment charges of $228 million in 2020 for owned and leased sand and crude-by-rail assets, also in the United States segment. EOG recorded pretax impairment charges of $81 million in 2020 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Notes 13 and 14.

Risk Management Activities

Risk Management Activities	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management Activities	Risk Management Activities Commodity Price Transactions. 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. During 2022, 2021 and 2020, EOG elected not to designate any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounted for these 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) on Mark-to-Market Financial Commodity Derivative Contracts, net on the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss). The related cash flow impact is reflected in Cash Flows from Operating Activities. During 2022, 2021 and 2020, EOG recognized net gains (losses) on the mark-to-market of financial commodity derivative contracts of $(3,982) million, $(1,152) million and $1,145 million, respectively, which included cash received from (payments for) settlements of crude oil, NGLs and natural gas financial derivative contracts of $(3,501) million, $(638) million and $1,071 million, respectively. Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the year ended December 31, 2022 (closed) and remaining for 2023 and thereafter, as of December 31, 2022. Crude oil and NGLs 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 Volume (MBbld) Weighted Average January - March 2022 (closed) NYMEX 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 (closed) 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 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 Weighted Average Price Differential January - December 2022 (closed) 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 Weighted Average January - September 2022 (closed) NYMEX Henry Hub 725 $ 3.57 October - December 2022 (closed) (1) NYMEX Henry Hub 425 3.05 October - December 2022 (closed) NYMEX Henry Hub 300 4.32 January - December 2023 (closed) (1) NYMEX Henry Hub 425 3.05 January 2023 (closed) NYMEX Henry Hub 300 3.36 February - 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 Weighted Average Price January - December 2022 (closed) NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1) 210 $ 0.01 January - December 2023 NYMEX Henry Hub HSC Differential 135 0.01 January - December 2024 NYMEX Henry Hub HSC Differential 10 0.00 January - December 2025 NYMEX Henry Hub HSC Differential 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. Financial Commodity Derivatives Location on Balance Sheet. The following table sets forth the amounts and classification of EOG's outstanding derivative financial instruments at December 31, 2022 and 2021, respectively. Certain amounts may be presented on a net basis on the consolidated financial statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions): Fair Value at December 31, Description Location on Balance Sheet 2022 2021 Asset Derivatives Crude oil, NGLs and natural gas financial derivative contracts - Noncurrent portion Other Assets $ — $ 6 Liability Derivatives Crude oil, NGLs and natural gas financial derivative contracts - Current portion Liabilities from Price Risk Management Activities (1) $ 169 $ 269 Noncurrent Portion Other Liabilities (2) 371 37 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $287 million, partially offset by gross assets of $26 million and collateral posted with counterparties of $92 million, at December 31, 2022. (2) The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $606 million, partially offset by gross assets of $3 million and collateral posted with counterparties of $232 million, at December 31, 2022. 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 13). EOG evaluates its exposure 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. At December 31, 2022, EOG's net accounts receivable balance related to United States hydrocarbon sales included one receivable balance which accounted for more than 10% of the total balance. The receivable was due from a petroleum refinery company. The related amount was collected during early 2023. At December 31, 2021, EOG's net accounts receivable balance related to United States hydrocarbon sales included three receivable balances, each of which accounted for more than 10% of the total balance. The receivables were due from three petroleum refinery companies. The related amounts were collected during early 2022. In 2022 and 2021, all natural gas from EOG's Trinidad operations was sold to the National Gas Company of Trinidad and Tobago Limited and its subsidiary. In 2022 and 2021, all crude oil and condensate from EOG's Trinidad operations was sold to Heritage Petroleum Company Limited. Through May 2021, all natural gas from EOG's China operations was sold to Petrochina Company Limited. All of EOG's financial derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that (i) require EOG, if it is the party in a net liability position, to post collateral with the counterparty when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings or (ii) require the counterparty, if it is in a net liability position, to post collateral with EOG when the amount of the net liability exceeds the threshold level specified for the counterparty'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 financial derivatives under the ISDA to be settled immediately. See Note 13 for the aggregate fair value of all financial derivative instruments that were in a net liability position at December 31, 2022 and 2021. EOG had $324 million and $140 million of collateral posted at December 31, 2022 and 2021, respectively, and had no collateral held at December 31, 2022 and 2021.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value MeasurementsCertain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Consolidated Balance Sheets. An established fair value hierarchy prioritizes the relative reliability of inputs used in fair value measurements. The hierarchy gives highest priority to Level 1 inputs that represent unadjusted quoted market prices in active markets for identical assets and liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs are directly or indirectly observable inputs other than quoted prices included within Level 1. Level 3 inputs are unobservable inputs and have the lowest priority in the hierarchy. EOG gives consideration to the credit risk of its counterparties, as well as its own credit risk, when measuring financial assets and liabilities at fair value. Recurring Fair Value Measurements. 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 December 31, 2022 and 2021 (in millions): Fair Value Measurements Using: Quoted Significant Significant Total At December 31, 2022 Financial Assets: Natural Gas Basis Swaps $ — $ 29 $ — $ 29 Financial Liabilities: Natural Gas Swaps — 703 — 703 Crude Oil Swaps — 190 — 190 At December 31, 2021 Financial Assets: Natural Gas Swaps $ — $ 29 $ — $ 29 Natural Gas Basis Swaps — 2 — 2 Crude Oil Swaps — 15 — 15 Financial Liabilities: Crude Oil Roll Differential Swaps — 24 — 24 Natural Gas Swaps — 121 — 121 Crude Oil Swaps — 340 — 340 Natural Gas Basis Swaps — 1 — 1 See Note 12 for the balance sheet amounts and classification of EOG's financial derivative instruments at December 31, 2022 and 2021. The estimated fair value of crude oil, NGLs and natural gas financial derivative contracts (including options/collars) 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 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 15. 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 group. If the expected undiscounted future cash flows, based on EOG's estimate of (and assumptions regarding) significant Level 3 inputs, including 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 using the Income Approach described in the Fair Value Measurement Topic of the ASC. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value. During 2022, proved oil and gas properties with a carrying amount of $146 million were written down to their fair value of $26 million, resulting in pretax impairment charges of $120 million. During 2021, proved oil and gas properties with a carrying amount of $27 million were written down to their fair value of $7 million, resulting in pretax impairment charges of $20 million During 2020, due to the decline in commodity prices and revisions of asset retirement obligations for certain properties, proved oil and gas properties with a carrying amount of $1,587 million were written down to their fair value of $319 million, resulting in pretax impairment charges of $1,268 million. In addition, EOG recorded pretax impairment charges in 2020 of $72 million for a commodity price-related write-down of other assets. 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 10. Fair Value of Debt. At both December 31, 2022 and 2021, EOG had outstanding $4,890 million aggregate principal amount of senior notes, which had estimated fair values of approximately $4,740 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 year-end.

Impairment Expense

Impairment Expense	12 Months Ended
	Dec. 31, 2022
Impairment Expense [Abstract]
Impairment Expense	Impairment Expense Impairment expense was as follows for the years ended December 31, 2022, 2021 and 2020 (in millions): 2022 2021 2020 Proved properties (1) $ 120 $ 20 $ 1,268 Unproved properties (2) 206 310 472 Other assets (3) 29 28 300 Inventories 25 13 — Firm commitment contracts (4) 2 5 60 Total $ 382 $ 376 $ 2,100 (1) Impairments to proved oil and gas properties in 2020 included legacy and non-core natural gas and crude oil and combo plays. See Notes 1 and 13. (2) 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. Impairments of unproved oil and gas properties included $38 million in 2021 for the decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. Impairments of unproved oil and gas properties included charges of $252 million in 2020 for certain leasehold costs that are no longer expected to be developed before expiration in the United States. See Note 1. (3) Includes impairment charges for owned and leased sand and crude-by-rail assets of $228 million in 2020 (see Note 18) and a commodity price-related write-down of other assets of $72 million in 2020 (see Note 13). (4) Includes impairment charges of $60 million in 2020 for firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligations, Noncurrent [Abstract]
Asset Retirement Obligations	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 years ended December 31, 2022 and 2021 (in millions): 2022 2021 Carrying Amount at Beginning of Period $ 1,231 $ 1,217 Liabilities Incurred 100 81 Liabilities Settled (1) (215) (131) Accretion 43 44 Revisions 173 20 Foreign Currency Translations (4) — Carrying Amount at End of Period $ 1,328 $ 1,231 Current Portion $ 38 $ 43 Noncurrent Portion $ 1,290 $ 1,188 (1) Includes settlements related to asset sales and property exchanges. The current and noncurrent portions of EOG's asset retirement obligations are included in Current Liabilities - Other and Other Liabilities, respectively, on the Consolidated Balance Sheets.

Exploratory Well Costs

Exploratory Well Costs	12 Months Ended
	Dec. 31, 2022
Capitalized Exploratory Well Costs [Abstract]
Exploratory Well Costs	Exploratory Well Costs EOG's net changes in capitalized exploratory well costs for the years ended December 31, 2022, 2021 and 2020 are presented below (in millions): 2022 2021 2020 Balance at January 1 $ 7 $ 29 $ 26 Additions Pending the Determination of Proved Reserves 135 73 108 Reclassifications to Proved Properties (88) (41) (81) Costs Charged to Expense (1) (39) (54) (24) Balance at December 31 $ 15 $ 7 $ 29 (1) Includes capitalized exploratory well costs charged to either dry hole costs or impairments. 2022 2021 2020 Capitalized exploratory well costs that have been capitalized for a period of one year or less $ 15 $ 7 $ 26 Capitalized exploratory well costs that have been capitalized for a period greater than one year (1) — — 3 Balance at December 31 $ 15 $ 7 $ 29 Number of exploratory wells that have been capitalized for a period greater than one year — — 1

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2022
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures During 2022, EOG paid cash for property acquisitions of $393 million in the United States. Additionally during 2022, EOG recognized net gains on asset dispositions of $74 million and received proceeds of $349 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 2021, EOG paid cash for property acquisitions of $95 million in the United States. Additionally during 2021, EOG recognized net gains on asset dispositions of $17 million and received proceeds of $231 million primarily due to the sale of the China assets and the disposition of the Northwest Shelf assets in New Mexico. Additionally, in the fourth quarter of 2021, EOG signed a purchase and sale agreement for the sale of primarily producing properties in the Rocky Mountain area. At December 31, 2021, the book value of these assets and their related asset retirement obligations were $99 million and $105 million, respectively. During 2020, EOG paid cash for property acquisitions of $82 million in the United States and $38 million in Other International, primarily in Oman. Additionally during 2020, EOG recognized net losses on asset dispositions of $47 million primarily due to sales of proved properties and non-cash property exchanges of unproved leasehold in Texas and New Mexico and the disposition of the Marcellus Shale assets, and received proceeds of approximately $192 million.

Leases

Leases	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Leases	Leases Lease costs are classified by the function of the ROU asset. The lease costs related to exploration and development activities are initially included in the Oil and Gas Properties line on the Consolidated Balance Sheets and subsequently accounted for in accordance with the Extractive Industries - Oil and Gas Topic of the ASC. Variable lease cost represents costs incurred above the contractual minimum payments and other charges associated with leased equipment, primarily for drilling and fracturing contracts classified as operating leases. The components of lease cost for the years ended December 31, 2022, 2021 and 2020 were as follows (in millions): 2022 2021 2020 Operating Lease Cost (1) $ 282 $ 295 $ 393 Finance Lease Cost: Amortization of Lease Assets 36 39 21 Interest on Lease Liabilities 6 7 4 Variable Lease Cost 71 63 91 Short-Term Lease Cost 425 257 194 Total Lease Cost $ 820 $ 661 $ 703 (1) Operating lease cost includes impairment expenses of $35 million in 2020. The following table sets forth the amounts and classification of EOG's outstanding ROU assets and related lease liabilities at December 31, 2022 and 2021 and supplemental information for the years ended December 31, 2022 and 2021 (in millions, except lease terms and discount rates): Description Location on Balance Sheet 2022 2021 Assets Operating Leases Other Assets $ 846 $ 743 Finance Leases Property, Plant and Equipment, Net (1) 203 241 Total $ 1,049 $ 984 Liabilities Current Operating Leases Current Portion of Operating Lease Liabilities $ 296 $ 240 Finance Leases Current Portion of Long-Term Debt 33 37 Long-Term Operating Leases Other Liabilities 584 558 Finance Leases Long-Term Debt 182 213 Total $ 1,095 $ 1,048 (1) Finance lease assets are recorded net of accumulated amortization of $157 million and $119 million at December 31, 2022 and 2021, respectively. 2022 2021 Weighted Average Remaining Lease Term (in years): Operating Leases 4.9 5.3 Finance Leases 6.5 7.0 Weighted Average Discount Rate: Operating Leases 3.4 % 3.0 % Finance Leases 2.6 % 2.6 % Cash paid for leases for the years ended December 31, 2022, 2021 and 2020 was as follows (in millions): 2022 2021 2020 Repayment of Operating Lease Liabilities Associated with Operating Activities $ 199 $ 207 $ 223 Repayment of Operating Lease Liabilities Associated with Investing Activities 95 98 130 Repayment of Finance Lease Liabilities 35 37 19 Non-cash leasing activities for the year ended December 31, 2022, included the additions of $511 million of operating leases and no finance leases. Non-cash leasing activities for the year ended December 31, 2021, included the additions of $333 million of operating leases and $74 million of finance leases. Non-cash leasing activities for the year ended December 31, 2020, included the additions of $893 million of operating leases and $174 million of finance leases. At December 31, 2022, the future minimum lease payments under non-cancellable leases were as follows (in millions): Operating Leases Finance Leases 2023 $ 323 $ 37 2024 213 37 2025 106 36 2026 80 30 2027 70 30 2028 and Beyond 172 65 Total Lease Payments 964 235 Less: Discount to Present Value 84 20 Total Lease Liabilities 880 215 Less: Current Portion of Lease Liabilities 296 33 Long-Term Lease Liabilities $ 584 $ 182 At December 31, 2022, EOG had additional minimum lease payments of $622 million, which are expected to commence in 2023 with lease terms of one

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation. The consolidated financial statements of EOG include the accounts of all domestic and foreign subsidiaries. Any investments in unconsolidated affiliates, in which EOG is able to exercise significant influence, are accounted for using the equity method. All intercompany accounts and transactions have been eliminated. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (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.
Financial Instruments	Financial Instruments. EOG's financial instruments consist of cash and cash equivalents, financial commodity derivative contracts, accounts receivable, accounts payable and current and long-term debt. The carrying values of cash and cash equivalents, financial commodity derivative contracts, accounts receivable and accounts payable approximate fair value (see Notes 2 and 12). Effective January 1, 2020, EOG adopted the provisions of Accounting Standards Update (ASU) 2016-13, "Measurement of Credit Losses on Financial Instruments" (ASU 2016-13). EOG did not record an impact to retained earnings upon adoption and expects current and future credit losses to be immaterial. EOG continues to monitor the credit risk from third-party companies to determine if expected credit losses may become material.
Cash and Cash Equivalents	Cash and Cash Equivalents. EOG records as cash equivalents all highly liquid short-term investments with original maturities of three months or less.
Oil and Gas Operations	Oil and Gas Operations. EOG accounts for its crude oil and natural gas exploration and production activities under the successful efforts method of accounting. Oil and gas lease acquisition costs are capitalized when incurred. 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. If the unproved properties are determined to be productive, the appropriate related costs are transferred to proved oil and gas properties. Lease rentals are expensed as incurred. Oil and gas exploration costs, other than the costs of drilling exploratory wells, are expensed as incurred. The costs of drilling exploratory wells are capitalized pending determination of whether EOG has discovered commercial quantities of proved reserves. If commercial quantities of proved reserves are not discovered, such drilling costs are expensed. In some circumstances, it may be uncertain whether commercial quantities of proved reserves have been discovered when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the estimated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made (see Note 16). Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of crude oil and natural gas, are capitalized. Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account. Oil and gas properties are grouped in accordance with the provisions of the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field. Amortization rates are updated quarterly to reflect: 1) the addition of capital costs, 2) reserve revisions (upwards or downwards) and additions, 3) property acquisitions and/or property dispositions and 4) impairments. 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 group. If the expected undiscounted future cash flows, based on EOG's estimate 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 using the Income Approach described in the Fair Value Measurement Topic of the ASC. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.
Other Property, Plant and Equipment	Other Property, Plant and Equipment . Other property, plant and equipment consists of gathering and processing assets, compressors, buildings and leasehold improvements, computer hardware and software, vehicles, and furniture and fixtures. Other property, plant and equipment is generally depreciated on a straight-line basis over the estimated useful lives of the property, plant and equipment, which range from 3 years to 45 years.
Inventories	Inventories. Inventories consist primarily of tubular goods, materials for completion operations, well equipment and gathering lines held for use in the exploration for, and development and production of, crude oil, NGLs and natural gas reserves. EOG accounts for inventories at the lower of cost and net realizable value with adjustments made, as appropriate, to recognize any reductions in value.
Revenue Recognition	Revenue Recognition. EOG presents disaggregated revenues by type of commodity within its Consolidated Statements of Income (Loss) and Comprehensive Income (Loss) and by geographic areas defined as operating segments. See Note 11. Revenues are recognized for the sale of crude oil and condensate, NGLs and natural gas at the point control of the product is transferred to the customer, typically when production is delivered and title or risk of loss transfers to the customer. Arrangements for such sales are evidenced by signed contracts with prices typically based on stated market indices, with certain adjustments for product quality and geographic location. As EOG typically invoices customers shortly after performance obligations have been fulfilled, contract assets and contract liabilities are not recognized. The balances of accounts receivable from contracts with customers as of December 31, 2022 and 2021, were $2,340 million and $2,130 million, respectively, and are included in Accounts Receivable, Net on the Consolidated Balance Sheets. Losses incurred on receivables from contracts with customers are infrequent and have been immaterial. Certain arrangements provide for the sale of fixed quantities of commodities in future years with pricing mechanisms based on future market prices at time of delivery. EOG does not disclose the value of these obligations given the uncertainty of the future realized transaction price. Crude Oil and Condensate. EOG sells its crude oil and condensate production at the wellhead or further downstream at a contractually-specified delivery point. Revenue is recognized when control transfers to the customer based on contract terms which reflect prevailing market prices. Any costs incurred prior to the transfer of control, such as gathering and transportation, are recognized as Operating Expenses. Natural Gas Liquids. EOG delivers certain of its natural gas production to either EOG-owned processing facilities or third-party processing facilities, where extraction of NGLs occurs. For EOG-owned facilities, revenue is recognized after processing upon transfer of NGLs to a customer. For third-party facilities, extracted NGLs are sold to the owner of the processing facility at the tailgate, or EOG takes possession and sells the extracted NGLs at the tailgate or exercises its option to sell further downstream to various customers. Under typical arrangements for third-party facilities, revenue is recognized after processing upon the transfer of control of the NGLs, either at the tailgate of the processing plant or further downstream. EOG recognizes revenues based on contract terms which reflect prevailing market prices, with any costs prior to the transfer of control, such as processing, transportation and fractionation fees, recognized as Transportation Costs and Gathering and Processing Costs, as appropriate. Natural Gas. EOG sells its natural gas production either at the wellhead or further downstream at a contractually-specified delivery point. In connection with the extraction of NGLs, EOG sells residue gas under separate agreements. Typically, EOG takes possession of the natural gas at the tailgate of the processing facility and sells it at the tailgate or further downstream. In each case, EOG recognizes revenues when control transfers to the customer, based on contract terms which reflect prevailing market prices. Gathering, Processing and Marketing. Gathering, processing and marketing revenues represent sales of third-party crude oil and condensate, NGLs and natural gas, as well as fees associated with gathering and processing third-party natural gas and revenues from sales of EOG-owned sand. EOG evaluates whether it is the principal or agent under these transactions. As control of the underlying commodity is transferred to EOG prior to the gathering, processing and marketing activities, EOG considers itself the principal of these arrangements. Accordingly, EOG recognizes these transactions on a gross basis. Purchases of third-party commodities are recorded as Marketing Costs, with sales of third-party commodities and fees received for gathering and processing recorded as Gathering, Processing and Marketing revenues.
Capitalized Interest Costs	Capitalized Interest Costs.  Interest costs have been capitalized as a part of the historical cost of unproved oil and gas properties.  The amount capitalized is an allocation of the interest cost incurred during the reporting period.  Capitalized interest is computed only during the exploration and development phases and ceases once production begins.  The interest rate used for capitalization purposes is based on the interest rates on EOG's outstanding borrowings.
Accounting for Risk Management Activities	Accounting for Risk Management Activities. Financial commodity derivative instruments are recorded on the balance sheet as either an asset or liability measured at fair value, and changes in the instrument's fair value are recognized currently in earnings unless specific hedge accounting criteria are met. During the three-year period ended December 31, 2022, EOG elected not to designate any of its financial commodity derivative instruments as accounting hedges and, accordingly, changes in the fair value of these outstanding derivative instruments are recognized as gains or losses in the period of change. The gains or losses are recorded as Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts on the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss). The related cash flow impact of settled contracts is reflected as cash flows from operating activities. EOG employs net presentation of financial commodity derivative assets and liabilities for financial reporting purposes when such assets and liabilities are with the same counterparty and subject to a master netting arrangement. See Note 12.
Income Taxes	Income Taxes. Income taxes are accounted for using the asset and liability approach. Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis. EOG assesses the realizability of deferred tax assets and recognizes valuation allowances as appropriate. See Note 6. Effective January 1, 2021, EOG adopted the provisions of ASU 2019-12, "Income Taxes (Topic 740) Simplifying the Accounting for Income Taxes" (ASU 2019-12). There was no impact upon adoption of ASU 2019-12 to EOG's consolidated financial statements or related disclosures.
Foreign Currency Translation	Foreign Currency Translation. The United States dollar is the functional currency for all of EOG's consolidated subsidiaries except for its Canadian subsidiaries, for which the functional currency is the Canadian dollar. For subsidiaries whose functional currency is deemed to be other than the United States dollar, asset and liability accounts are translated at year-end exchange rates and revenues and expenses are translated at average exchange rates prevailing during the year. Translation adjustments are included in Accumulated Other Comprehensive Loss on the Consolidated Balance Sheets. Any gains or losses on transactions or monetary assets or liabilities in currencies other than the functional currency are included in net income (loss) in the current period. See Note 4.
Net Income (Loss) Per Share	Net Income (Loss) Per Share. Basic net income (loss) per share is computed on the basis of the weighted-average number of common shares outstanding during the period. Diluted net income (loss) per share is computed based upon the weighted-average number of common shares outstanding during the period plus the assumed issuance of common shares for all potentially dilutive securities. See Note 9.
Stock-Based Compensation	Stock-Based Compensation . EOG measures the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award. See Note 7.
Leases	Leases. In the ordinary course of business, EOG enters into contracts for drilling, fracturing, compression, real estate and other services which contain equipment and other assets and that meet the definition of a lease under ASC "Leases (Topic 842)." The lease term for these contracts, which includes any renewals at EOG's option that are reasonably certain to be exercised, ranges from one month to 30 years. Right of Use (ROU) assets and related liabilities are recognized on the commencement date on the Consolidated Balance Sheets based on future lease payments, discounted based on the rate implicit in the contract, if readily determinable, or EOG's incremental borrowing rate commensurate with the lease term of the contract. EOG estimates its incremental borrowing rate based on the approximate rate required to borrow on a collateralized basis. Contracts with lease terms of less than 12 months are not recorded on the Consolidated Balance Sheets, but instead are disclosed as short-term lease cost. EOG has elected not to separate non-lease components from all leases, excluding those for fracturing services, real estate and produced water disposal, as lease payments under these contracts contain significant non-lease components, such as labor and operating costs. See Note 18.
Recently Issued Accounting Standards	Recently Issued Accounting Standards. In March 2020, the FASB issued 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.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Schedule of Long-Term Debt	Long-Term Debt at December 31, 2022 and 2021 consisted of the following (in millions): 2022 2021 2.625% Senior Notes due 2023 $ 1,250 $ 1,250 3.15% Senior Notes due 2025 500 500 4.15% Senior Notes due 2026 750 750 6.65% Senior Notes due 2028 140 140 4.375% Senior Notes due 2030 750 750 3.90% Senior Notes due 2035 500 500 5.10% Senior Notes due 2036 250 250 4.950% Senior Notes due 2050 750 750 Long-Term Debt 4,890 4,890 Finance Leases (see Note 18) 215 250 Less: Current Portion of Long-Term Debt 1,283 37 Unamortized Debt Discount 23 27 Debt Issuance Costs 4 4 Total Long-Term Debt $ 3,795 $ 5,072

Stockholder's Equity (Tables)

Stockholder's Equity (Tables)	12 Months Ended
	Dec. 31, 2022
Stockholders' Equity Note [Abstract]
Schedule of Common Stock Activity	The following summarizes Common Stock activity for each of the years ended December 31, 2022, 2021 and 2020 (in thousands): Common Shares Issued Treasury Outstanding Balance at December 31, 2019 582,213 (299) 581,914 Common Stock Issued Under Stock-Based Compensation Plans 1,482 — 1,482 Treasury Stock Purchased (1) — (389) (389) Common Stock Issued Under Employee Stock Purchase Plan — 377 377 Treasury Stock Issued Under Stock-Based Compensation Plans — 187 187 Balance at December 31, 2020 583,695 (124) 583,571 Common Stock Issued Under Stock-Based Compensation Plans 1,511 — 1,511 Treasury Stock Purchased (1) — (504) (504) Common Stock Issued Under Employee Stock Purchase Plan 316 — 316 Treasury Stock Issued Under Stock-Based Compensation Plans — 371 371 Balance at December 31, 2021 585,522 (257) 585,265 Common Stock Issued Under Stock-Based Compensation Plans 2,674 — 2,674 Treasury Stock Purchased (1) — (997) (997) Common Stock Issued Under Employee Stock Purchase Plan 201 — 201 Treasury Stock Issued Under Stock-Based Compensation Plans — 554 554 Balance at December 31, 2022 588,397 (700) 587,697

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The components of Accumulated Other Comprehensive Loss at December 31, 2022 and 2021 consisted of the following (in millions): Foreign Currency Translation Adjustment Other Total December 31, 2020 $ (10) $ (2) $ (12) Other comprehensive income (loss) before taxes (1) 1 — Tax effects — — — Other comprehensive loss (1) 1 — December 31, 2021 (11) (1) (12) Other comprehensive income (loss) before taxes 4 — 4 Tax effects — — — Other comprehensive income (loss) 4 — 4 December 31, 2022 $ (7) $ (1) $ (8)

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Schedule of Deferred Income Tax Assets (Liabilities), Net	The principal components of EOG's total net deferred income tax liabilities at December 31, 2022 and 2021 were as follows (in millions): 2022 2021 Deferred Income Tax Assets (Liabilities) Foreign Oil and Gas Exploration and Development Costs Deducted for Tax Under Book Depreciation, Depletion and Amortization $ (18) $ (19) Foreign Asset Retirement Obligations 81 51 Foreign Accrued Expenses and Liabilities 13 15 Foreign Net Operating Loss 82 80 Foreign Valuation Allowances (116) (111) Foreign Other (9) (5) Total Net Deferred Income Tax Assets $ 33 $ 11 Deferred Income Tax (Assets) Liabilities Oil and Gas Exploration and Development Costs Deducted for Tax Over Book Depreciation, Depletion and Amortization $ 5,291 $ 5,063 Financial Commodity Derivative Contracts (421) (97) Deferred Compensation Plans (58) (57) Equity Awards (60) (86) Other (42) (74) Total Net Deferred Income Tax Liabilities $ 4,710 $ 4,749 Total Net Deferred Income Tax Liabilities $ 4,677 $ 4,738
Schedule of Components of Income (Loss) Before Income Taxes	The components of Income (Loss) Before Income Taxes for the years indicated below were as follows (in millions): 2022 2021 2020 United States $ 9,752 $ 5,787 $ (756) Foreign 149 146 17 Total $ 9,901 $ 5,933 $ (739)
Schedule of Components of Income Tax Provision (Benefit)	The principal components of EOG's Income Tax Provision (Benefit) for the years indicated below were as follows (in millions): 2022 2021 2020 Current: Federal $ 2,020 $ 1,203 $ (108) State 126 85 7 Foreign 62 105 40 Total 2,208 1,393 (61) Deferred: Federal (2) (41) (153) State (37) (62) (15) Foreign (22) (19) (18) Total (61) (122) (186) Other Non-Current: (1) Federal — — 113 Foreign (5) (2) — Total (5) (2) 113 Income Tax Provision (Benefit) $ 2,142 $ 1,269 $ (134) (1) Includes changes in certain amounts that are expected to be paid or received beyond the next twelve months. The primary component in 2020 is refundable alternative minimum tax (AMT) credits.
Schedule of Tax Rate Reconciliation	The differences between taxes computed at the U.S. federal statutory tax rate and EOG's effective rate for the years indicated below were as follows: 2022 2021 2020 Statutory Federal Income Tax Rate 21.0 % 21.0 % 21.0 % State Income Tax, Net of Federal Benefit 0.7 0.3 0.9 Income Tax Provision Related to Foreign Operations — 0.9 (0.1) Income Tax Provision Related to Canadian Operations — — (2.4) Stock-Based Compensation — 0.2 (2.9) Other — (1.0) 1.7 Effective Income Tax Rate 21.7 % 21.4 % 18.2 %
Schedule of Valuation Allowance	The principal components of EOG's rollforward of valuation allowances for deferred income tax assets for the years indicated below were as follows (in millions): 2022 2021 2020 Beginning Balance $ 219 $ 219 $ 201 Increase (1) 27 15 25 Decrease (2) (33) (14) (11) Other (3) (6) (1) 4 Ending Balance $ 207 $ 219 $ 219 (1) Increase in valuation allowance related to the generation of tax NOLs and other deferred tax assets. (2) Decrease in valuation allowance associated with adjustments to certain deferred tax assets and their related allowances.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2022
Share-Based Payment Arrangement [Abstract]
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs	Stock-based compensation expense is included on the Consolidated Statements of Income (Loss) and Comprehensive Income (Loss) based upon the job functions of the employees receiving the grants. Compensation expense related to EOG's stock-based compensation plans for the years ended December 31, 2022, 2021 and 2020 was as follows (in millions): 2022 2021 2020 Lease and Well $ 40 $ 49 $ 52 Gathering and Processing Costs 4 3 1 Exploration Costs 15 20 21 General and Administrative 74 80 72 Total $ 133 $ 152 $ 146
Schedule of Vesting	The vesting schedules for grants of stock options, SARs, restricted stock and restricted stock units, and Performance Units are generally as follows: Grant Type Vesting Schedule Stock Options/SARs Vesting in increments of one-third on each of the first three anniversaries, respectively, of the date of grant Restricted Stock/Restricted Stock Units "Cliff" vesting three years from the date of grant Performance Units "Cliff" vesting on the February 28th following the three
Schedule of Weighted Average Fair Values and Valuation Assumptions	Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants for the years ended December 31, 2022, 2021 and 2020 were as follows: Stock Options/SARs ESPP 2022 2021 2020 2022 2021 2020 Weighted Average Fair Value of Grants $ 28.30 $ 24.92 $ 11.06 $ 26.62 $ 18.12 $ 19.14 Expected Volatility 42.20 % 42.24 % 44.47 % 43.00 % 51.27 % 53.48 % Risk-Free Interest Rate 0.89 % 0.50 % 0.21 % 1.30 % 0.07 % 0.90 % Dividend Yield 3.28 % 2.26 % 3.27 % 2.89 % 2.89 % 2.27 % Expected Life 5.3 years 5.2 years 5.2 years 0.5 years 0.5 years 0.5 years
Schedule of Share Based Compensation Arrangement By Share Based Payment Award	The following table sets forth the stock option and SAR transactions for the years ended December 31, 2022, 2021 and 2020 (stock options and SARs in thousands): 2022 2021 2020 Number Weighted Number Weighted Number Weighted Outstanding at January 1 9,969 $ 84.37 10,186 $ 84.08 9,395 $ 94.53 Granted 2 97.64 1,982 81.68 1,996 37.63 Exercised (1) (5,526) 89.70 (1,130) 63.98 (23) 69.59 Forfeited (220) 82.74 (1,069) 98.15 (1,182) 88.93 Outstanding at December 31 4,225 77.49 9,969 84.37 10,186 84.08 Stock Options/SARs Exercisable at December 31 2,462 84.53 6,197 95.33 6,343 96.41 (1) The total intrinsic value of stock options/SARs exercised during the years 2022, 2021 and 2020 was $190 million, $27 million and $0.4 million, respectively. The intrinsic value is based upon the difference between the market price of the Common Stock on the date of exercise and the grant price of the stock options/SARs.
Schedule of Stock Options and SARs Outstanding and Exercisable	The following table summarizes certain information for the stock options and SARs outstanding and exercisable at December 31, 2022 (stock options and SARs in thousands): Stock Options/SARs Outstanding Stock Options/SARs Exercisable Range of Stock Weighted Weighted Aggregate Intrinsic Value (1) Stock Weighted Weighted Aggregate Intrinsic Value (1) $ 34.00 to $ 52.99 1,029 4 $ 37.52 466 4 $ 37.51 53.00 to 80.99 593 3 74.98 584 3 75.04 81.00 to 81.99 1,513 6 81.81 331 5 81.81 82.00 to 96.99 562 1 95.62 553 1 95.75 97.00 to 129.99 528 3 126.51 528 3 126.53 4,225 4 77.49 $ 220 2,462 3 84.53 $ 111 (1) Based upon the difference between the closing market price of the Common Stock on the last trading day of the year and the grant price of in-the-money stock options and SARs, in millions.
Schedule of ESPP Activity	The following table summarizes ESPP activity for the years ended December 31, 2022, 2021 and 2020 (in thousands, except number of participants): 2022 2021 2020 Approximate Number of Participants 1,969 2,036 2,063 Shares Purchased 201 316 377 Aggregate Purchase Price $ 17,250 $ 17,224 $ 16,103
Schedule of Restricted Stock and Restricted Stock Unit Transactions	The following table sets forth the restricted stock and restricted stock unit transactions for the years ended December 31, 2022, 2021 and 2020 (shares and units in thousands): 2022 2021 2020 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 4,680 $ 69.37 4,742 $ 74.97 4,546 $ 90.16 Granted 1,637 113.21 1,422 81.50 1,488 38.10 Released (1) (2,019) 81.76 (1,388) 101.00 (1,213) 85.92 Forfeited (185) 68.89 (96) 68.26 (79) 86.52 Outstanding at December 31 (2) 4,113 80.77 4,680 69.37 4,742 74.97 (1) (1) The total intrinsic value of restricted stock and restricted stock units released during the years ended December 31, 2022, 2021 and 2020 was $223 million, $110 million and $48 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date restricted stock and restricted stock units are released. (2) (2) The total intrinsic value of restricted stock and restricted stock units outstanding at December 31, 2022, 2021 and 2020 was $533 million, $416 million and $236 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year.
Schedule of Weighted Average Fair Values and Valuation Assumptions for Performance Units/Stocks	Weighted average fair values and valuation assumptions used to value Performance Units during the years ended December 31, 2022, 2021 and 2020 were as follows: 2022 2021 2020 Weighted Average Fair Value of Grants $ 126.55 $ 95.16 $ 42.77 Expected Volatility 56.11 % 53.80 % 47.27 % Risk-Free Interest Rate 4.01 % 0.59 % 0.16 %
Schedule of Performance Unit and Performance Stock Transactions	The following table sets forth the Performance Unit transactions for the years ended December 31, 2022, 2021 and 2020 (units in thousands): 2022 2021 2020 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 1 679 $ 84.97 613 $ 88.38 598 $ 103.91 Granted 122 126.55 222 95.16 172 42.77 Granted for Performance Multiple (1) — — 19 113.81 66 119.10 Released (2) (57) 136.74 (175) 113.06 (223) 103.87 Forfeited for Performance Multiple (3) (56) 136.74 — — — — Outstanding at December 31 (4) 688 (5) 83.82 679 84.97 613 88.38 (1) Upon completion of the performance period for the Performance Units granted in 2017 and 2016, a performance multiple of 125% and 150%, respectively, was applied to each of the grants resulting in additional grants of Performance Units in February 2021 and 2020. (2) The total intrinsic value of Performance Units released during the years ended December 31, 2022, 2021 and 2020 was $7 million, $13 million and $13 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date 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 December 31, 2022, 2021 and 2020 was $89 million, $60 million and $31 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Schedule of Minimum Commitments for Unrecorded Unconditional Purchase Obligations	At December 31, 2022, total minimum commitments from purchase and service obligations and transportation and storage service commitments not qualifying as leases, based on current transportation and storage rates and the foreign currency exchange rates used to convert Canadian dollars into United States dollars at December 31, 2022, were as follows (in millions): Total Minimum 2023 $ 1,362 2024 1,149 2025 984 2026 791 2027 642 2028 and beyond 1,570 $ 6,498

Net Income (Loss) Per Share (Ta

Net Income (Loss) Per Share (Tables)	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Schedule of Computation of Net Income Per Share	The following table sets forth the computation of Net Income (Loss) Per Share for the years ended December 31, 2022, 2021 and 2020 (in millions, except per share data): 2022 2021 2020 Numerator for Basic and Diluted Earnings per Share - Net Income (Loss) $ 7,759 $ 4,664 $ (605) Denominator for Basic Earnings per Share - Weighted Average Shares 583 581 579 Potential Dilutive Common Shares - Stock Options/SARs 2 — — Restricted Stock/Units and Performance Units 2 3 — Denominator for Diluted Earnings per Share - Adjusted Diluted Weighted Average Shares 587 584 579 Net Income (Loss) Per Share Basic $ 13.31 $ 8.03 $ (1.04) Diluted $ 13.22 $ 7.99 $ (1.04)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2022
Supplemental Cash Flow Information [Abstract]
Schedule of Net Cash Paid For Interest and Income Taxes	Net cash paid for (received from) interest and income taxes was as follows for the years ended December 31, 2022, 2021 and 2020 (in millions): 2022 2021 2020 Interest, Net of Capitalized Interest $ 173 $ 185 $ 205 Income Taxes, Net of Refunds Received $ 2,475 $ 1,114 $ (206)

Business Segment Information (T

Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Schedule of Selected Financial Information by Reportable Segment	Financial information by reportable segment is presented below as of and for the years ended December 31, 2022, 2021 and 2020 (in millions): United Trinidad Other International (1) Total 2022 Crude Oil and Condensate $ 16,349 $ 18 $ — $ 16,367 Natural Gas Liquids 2,648 — — 2,648 Natural Gas 3,489 292 — 3,781 Losses on Mark-to-Market Financial Commodity Derivative Contracts, Net (3,982) — — (3,982) Gathering, Processing and Marketing 6,695 1 — 6,696 Gains (Losses) on Asset Dispositions, Net 77 (4) 1 74 Other, Net 118 — — 118 Operating Revenues and Other (2) 25,394 307 1 25,702 Depreciation, Depletion and Amortization 3,469 73 — 3,542 Operating Income (Loss) (3) 9,880 122 (36) 9,966 Interest Income 81 2 2 85 Other Income (Expense) (17) 46 — 29 Net Interest Expense 179 — — 179 Income (Loss) Before Income Taxes 9,765 170 (34) 9,901 Income Tax Provision 2,106 35 1 2,142 Additions to Oil and Gas Properties, Excluding Dry Hole Costs 4,599 122 6 4,727 Total Property, Plant and Equipment, Net 29,109 307 13 29,429 Total Assets 40,349 879 143 41,371 2021 Crude Oil and Condensate $ 11,094 $ 31 $ — $ 11,125 Natural Gas Liquids 1,812 — — 1,812 Natural Gas 2,156 270 18 2,444 Losses on Mark-to-Market Financial Commodity Derivative Contracts, Net (1,152) — — (1,152) Gathering, Processing and Marketing 4,287 1 — 4,288 Gains (Losses) on Asset Dispositions, Net (40) (2) 59 17 Other, Net 108 — — 108 Operating Revenues and Other (4) 18,265 300 77 18,642 Depreciation, Depletion and Amortization 3,558 87 6 3,651 Operating Income (Loss) (5) 6,013 151 (62) 6,102 Interest Income 3 — — 3 Other Income (Expense) (14) 8 12 6 Net Interest Expense 178 — — 178 Income (Loss) Before Income Taxes 5,824 159 (50) 5,933 Income Tax Provision (Benefit) 1,247 66 (44) 1,269 Additions to Oil and Gas Properties, Excluding Dry Hole Costs 3,557 55 5 3,617 Total Property, Plant and Equipment, Net 28,213 204 9 28,426 Total Assets 37,436 637 163 38,236 United Trinidad Other International (1) Total 2020 Crude Oil and Condensate $ 5,774 $ 11 $ 1 $ 5,786 Natural Gas Liquids 668 — — 668 Natural Gas 614 169 54 837 Gains on Mark-to-Market Financial Commodity Derivative Contracts, Net 1,145 — — 1,145 Gathering, Processing and Marketing 2,581 2 — 2,583 Losses on Asset Dispositions, Net (47) — — (47) Other, Net 60 — — 60 Operating Revenues and Other (6) 10,795 182 55 11,032 Depreciation, Depletion and Amortization 3,324 60 16 3,400 Operating Income (Loss) (7) (546) 75 (73) (544) Interest Income 11 1 — 12 Other Expense — (2) — (2) Net Interest Expense 205 — — 205 Income (Loss) Before Income Taxes (740) 74 (73) (739) Income Tax Provision (Benefit) (157) 15 8 (134) (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 had sales activity with three significant purchasers in 2022, one totaling $3.3 billion, another totaling $3.1 billion and a third totaling $3.0 billion of consolidated Operating Revenues and Other in the United States segment. (3) EOG recorded pretax impairment charges of $15 million in 2022 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Note 14. (4) EOG had sales activity with two significant purchasers in 2021, one totaling $2.7 billion and the other totaling $2.6 billion of consolidated Operating Revenues and Other in the United States segment. (5) EOG recorded pretax impairment charges of $45 million and dry hole costs of $42 million in 2021 in the Other International segment related to its decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. In addition, EOG recorded net gains of asset dispositions of $58 million in 2021 in the Other International segment during the second quarter of 2021 due to the sale of its China operations. See Notes 14 and 17, respectively. (6) EOG had sales activity with three significant purchasers in 2020, each totaling $1.1 billion of consolidated Operating Revenues and Other in the United States segment. (7) EOG recorded pretax impairment charges of $1,570 million in 2020 for proved oil and gas properties, leasehold costs and other assets due to the decline in commodity prices and revisions of asset retirement obligations for certain properties in the United States segment. In addition, EOG recorded pretax impairment charges of $228 million in 2020 for owned and leased sand and crude-by-rail assets, also in the United States segment. EOG recorded pretax impairment charges of $81 million in 2020 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Notes 13 and 14.

Risk Management Activities (Tab

Risk Management Activities (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the year ended December 31, 2022 (closed) and remaining for 2023 and thereafter, as of December 31, 2022. Crude oil and NGLs 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 Volume (MBbld) Weighted Average January - March 2022 (closed) NYMEX 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 (closed) 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 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 Weighted Average Price Differential January - December 2022 (closed) 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 Weighted Average January - September 2022 (closed) NYMEX Henry Hub 725 $ 3.57 October - December 2022 (closed) (1) NYMEX Henry Hub 425 3.05 October - December 2022 (closed) NYMEX Henry Hub 300 4.32 January - December 2023 (closed) (1) NYMEX Henry Hub 425 3.05 January 2023 (closed) NYMEX Henry Hub 300 3.36 February - December 2023 NYMEX Henry Hub 300 3.36 January - December 2024 NYMEX Henry Hub 725 3.07 January - December 2025 NYMEX Henry Hub 725 3.07 _________________ Natural Gas Basis Swap Contracts Contracts Sold Period Settlement Index Volume Weighted Average Price January - December 2022 (closed) NYMEX Henry Hub Houston Ship Channel (HSC) Differential (1) 210 $ 0.01 January - December 2023 NYMEX Henry Hub HSC Differential 135 0.01 January - December 2024 NYMEX Henry Hub HSC Differential 10 0.00 January - December 2025 NYMEX Henry Hub HSC Differential 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.
Schedule of Derivative Instruments In Statement Of Financial Position, Fair Value	The following table sets forth the amounts and classification of EOG's outstanding derivative financial instruments at December 31, 2022 and 2021, respectively. Certain amounts may be presented on a net basis on the consolidated financial statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions): Fair Value at December 31, Description Location on Balance Sheet 2022 2021 Asset Derivatives Crude oil, NGLs and natural gas financial derivative contracts - Noncurrent portion Other Assets $ — $ 6 Liability Derivatives Crude oil, NGLs and natural gas financial derivative contracts - Current portion Liabilities from Price Risk Management Activities (1) $ 169 $ 269 Noncurrent Portion Other Liabilities (2) 371 37 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $287 million, partially offset by gross assets of $26 million and collateral posted with counterparties of $92 million, at December 31, 2022. (2) The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $606 million, partially offset by gross assets of $3 million and collateral posted with counterparties of $232 million, at December 31, 2022.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis	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 December 31, 2022 and 2021 (in millions): Fair Value Measurements Using: Quoted Significant Significant Total At December 31, 2022 Financial Assets: Natural Gas Basis Swaps $ — $ 29 $ — $ 29 Financial Liabilities: Natural Gas Swaps — 703 — 703 Crude Oil Swaps — 190 — 190 At December 31, 2021 Financial Assets: Natural Gas Swaps $ — $ 29 $ — $ 29 Natural Gas Basis Swaps — 2 — 2 Crude Oil Swaps — 15 — 15 Financial Liabilities: Crude Oil Roll Differential Swaps — 24 — 24 Natural Gas Swaps — 121 — 121 Crude Oil Swaps — 340 — 340 Natural Gas Basis Swaps — 1 — 1

Impairment Expense (Tables)

Impairment Expense (Tables)	12 Months Ended
	Dec. 31, 2022
Impairment Expense [Abstract]
Schedule of Impairment Expenses	Impairment expense was as follows for the years ended December 31, 2022, 2021 and 2020 (in millions): 2022 2021 2020 Proved properties (1) $ 120 $ 20 $ 1,268 Unproved properties (2) 206 310 472 Other assets (3) 29 28 300 Inventories 25 13 — Firm commitment contracts (4) 2 5 60 Total $ 382 $ 376 $ 2,100 (1) Impairments to proved oil and gas properties in 2020 included legacy and non-core natural gas and crude oil and combo plays. See Notes 1 and 13. (2) 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. Impairments of unproved oil and gas properties included $38 million in 2021 for the decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. Impairments of unproved oil and gas properties included charges of $252 million in 2020 for certain leasehold costs that are no longer expected to be developed before expiration in the United States. See Note 1. (3) Includes impairment charges for owned and leased sand and crude-by-rail assets of $228 million in 2020 (see Note 18) and a commodity price-related write-down of other assets of $72 million in 2020 (see Note 13). (4) Includes impairment charges of $60 million in 2020 for firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligations, Noncurrent [Abstract]
Schedule of Asset Retirement Obligation Rollforward Analysis	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 years ended December 31, 2022 and 2021 (in millions): 2022 2021 Carrying Amount at Beginning of Period $ 1,231 $ 1,217 Liabilities Incurred 100 81 Liabilities Settled (1) (215) (131) Accretion 43 44 Revisions 173 20 Foreign Currency Translations (4) — Carrying Amount at End of Period $ 1,328 $ 1,231 Current Portion $ 38 $ 43 Noncurrent Portion $ 1,290 $ 1,188 (1) Includes settlements related to asset sales and property exchanges.

Exploratory Well Costs (Tables)

Exploratory Well Costs (Tables)	12 Months Ended
	Dec. 31, 2022
Capitalized Exploratory Well Costs [Abstract]
Schedule of Net Changes in Capitalized Exploratory Well Costs	EOG's net changes in capitalized exploratory well costs for the years ended December 31, 2022, 2021 and 2020 are presented below (in millions): 2022 2021 2020 Balance at January 1 $ 7 $ 29 $ 26 Additions Pending the Determination of Proved Reserves 135 73 108 Reclassifications to Proved Properties (88) (41) (81) Costs Charged to Expense (1) (39) (54) (24) Balance at December 31 $ 15 $ 7 $ 29 (1) Includes capitalized exploratory well costs charged to either dry hole costs or impairments.
Schedule of Aging of Capitalized Exploratory Well Costs	2022 2021 2020 Capitalized exploratory well costs that have been capitalized for a period of one year or less $ 15 $ 7 $ 26 Capitalized exploratory well costs that have been capitalized for a period greater than one year (1) — — 3 Balance at December 31 $ 15 $ 7 $ 29 Number of exploratory wells that have been capitalized for a period greater than one year — — 1

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Schedule of Lease	The components of lease cost for the years ended December 31, 2022, 2021 and 2020 were as follows (in millions): 2022 2021 2020 Operating Lease Cost (1) $ 282 $ 295 $ 393 Finance Lease Cost: Amortization of Lease Assets 36 39 21 Interest on Lease Liabilities 6 7 4 Variable Lease Cost 71 63 91 Short-Term Lease Cost 425 257 194 Total Lease Cost $ 820 $ 661 $ 703 (1) Operating lease cost includes impairment expenses of $35 million in 2020.
Schedule of Outstanding Lease Assets And Lease Liabilities	The following table sets forth the amounts and classification of EOG's outstanding ROU assets and related lease liabilities at December 31, 2022 and 2021 and supplemental information for the years ended December 31, 2022 and 2021 (in millions, except lease terms and discount rates): Description Location on Balance Sheet 2022 2021 Assets Operating Leases Other Assets $ 846 $ 743 Finance Leases Property, Plant and Equipment, Net (1) 203 241 Total $ 1,049 $ 984 Liabilities Current Operating Leases Current Portion of Operating Lease Liabilities $ 296 $ 240 Finance Leases Current Portion of Long-Term Debt 33 37 Long-Term Operating Leases Other Liabilities 584 558 Finance Leases Long-Term Debt 182 213 Total $ 1,095 $ 1,048 (1) Finance lease assets are recorded net of accumulated amortization of $157 million and $119 million at December 31, 2022 and 2021, respectively.
Schedule of Weighted Average Remaining Lease Term And Discount Rate	2022 2021 Weighted Average Remaining Lease Term (in years): Operating Leases 4.9 5.3 Finance Leases 6.5 7.0 Weighted Average Discount Rate: Operating Leases 3.4 % 3.0 % Finance Leases 2.6 % 2.6 %
Schedule of Cash Paid for Leases	Cash paid for leases for the years ended December 31, 2022, 2021 and 2020 was as follows (in millions): 2022 2021 2020 Repayment of Operating Lease Liabilities Associated with Operating Activities $ 199 $ 207 $ 223 Repayment of Operating Lease Liabilities Associated with Investing Activities 95 98 130 Repayment of Finance Lease Liabilities 35 37 19
Schedule of Operating And Finance Non-Cancellable Leases Maturity	At December 31, 2022, the future minimum lease payments under non-cancellable leases were as follows (in millions): Operating Leases Finance Leases 2023 $ 323 $ 37 2024 213 37 2025 106 36 2026 80 30 2027 70 30 2028 and Beyond 172 65 Total Lease Payments 964 235 Less: Discount to Present Value 84 20 Total Lease Liabilities 880 215 Less: Current Portion of Lease Liabilities 296 33 Long-Term Lease Liabilities $ 584 $ 182

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Accounts receivable from contracts with customers	$ 2,340	$ 2,130
Minimum
Property, plant and equipment, useful life	3 years
Lease term	1 month
Maximum
Property, plant and equipment, useful life	45 years
Lease term	30 years
Revolving Credit Facility | Revolving Credit Agreement (New Facility)
Maximum borrowing capacity	$ 2,000

Long-Term Debt - Schedule of Lo

Long-Term Debt - Schedule of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-Term Debt	$ 4,890	$ 4,890
Finance Leases (see Note 18)	215	250
Less: Current Portion of Long-Term Debt	1,283	37
Unamortized Debt Discount	23	27
Debt Issuance Costs	4	4
Total Long-Term Debt	$ 3,795	5,072
2.625% Senior Notes due 2023
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	2.625%
Long-Term Debt	$ 1,250	1,250
3.15% Senior Notes due 2025
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	3.15%
Long-Term Debt	$ 500	500
4.15% Senior Notes due 2026
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	4.15%
Long-Term Debt	$ 750	750
6.65% Senior Notes due 2028
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	6.65%
Long-Term Debt	$ 140	140
4.375% Senior Notes due 2030
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	4.375%
Long-Term Debt	$ 750	750
3.90% Senior Notes due 2035
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	3.90%
Long-Term Debt	$ 500	500
5.10% Senior Notes due 2036
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	5.10%
Long-Term Debt	$ 250	250
4.950% Senior Notes due 2050
Debt Instrument [Line Items]
Debt instrument, interest rate (as a percent)	4.95%
Long-Term Debt	$ 750	$ 750

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details)	12 Months Ended
	Dec. 31, 2022 USD ($) Term	Dec. 31, 2021 USD ($)	Feb. 01, 2021 USD ($)
Long-Term Debt by Maturity [Abstract]
Aggregate annual maturity of long-term debt (excluding capital lease obligations) in 2023	$ 1,250,000,000
Aggregate annual maturity of long-term debt (excluding capital lease obligations) in 2024	0
Aggregate annual maturity of long-term debt (excluding capital lease obligations) in 2025	500,000,000
Aggregate annual maturity of long-term debt (excluding capital lease obligations) in 2026	750,000,000
Aggregate annual maturity of long-term debt (excluding capital lease obligations) in 2027	$ 0
Senior Unsecured Revolving Credit Agreement Due 2024
Long-Term Debt by Maturity [Abstract]
Line of credit facility, mature date	Jun. 27, 2024
Revolving Credit Facility | Revolving Credit Agreement (New Facility)
Long-Term Debt by Maturity [Abstract]
Maximum borrowing capacity	$ 2,000,000,000
Line of credit facility, maturity term extensions | Term	2
Line of credit facility, extension period	1 year
Line of credit facility increase additional borrowings (not to exceed)	$ 3,000,000,000
Maximum total debt-to-total capitalization ratio allowed under financial covenant (in hundredths)	65%
Long-Term Line of Credit	$ 0	$ 0
Revolving Credit Facility | Revolving Credit Agreement (New Facility) | Eurodollar
Long-Term Debt by Maturity [Abstract]
Weighted average interest rate (in hundredths)	5.29%
Revolving Credit Facility | Revolving Credit Agreement (New Facility) | Base Rate
Long-Term Debt by Maturity [Abstract]
Weighted average interest rate (in hundredths)	7.50%
Commercial Paper
Long-Term Debt by Maturity [Abstract]
Line of credit facility, current borrowing capacity	$ 0	$ 0
Senior Notes | Senior Notes Due 2021
Long-Term Debt by Maturity [Abstract]
Debt instrument, face amount			$ 750,000,000
Debt instrument, interest rate (as a percent)			4.10%

Stockholder's Equity (Details)

Stockholder's Equity (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Billions	Feb. 23, 2023	Nov. 03, 2022	Sep. 29, 2022	Aug. 04, 2022	May 05, 2022	Feb. 24, 2022	Nov. 04, 2021	May 06, 2021	Feb. 25, 2021	Feb. 27, 2020	Dec. 31, 2022	Sep. 30, 2001
Common Stock Activity [Line Items]
An aggregate maximum of shares of common stock authorized for repurchase (in shares)												10
Stock repurchase program, authorized amount							$ 5
Stock repurchase program, remaining authorized repurchase amount											$ 5
Common stock dividends declared (in USD per share)		$ 0.75	$ 0.75		$ 0.75	$ 0.75	$ 0.4125	$ 0.4125	$ 0.375	$ 0.2875
Common stock special cash dividends per share declared (in usd per share)		1.50		$ 1.50	$ 1.80	$ 1	2	$ 1
Dividends payable, amount per share after increase (in usd per share)		$ 0.825					$ 0.75		$ 0.4125	$ 0.375
Subsequent Event
Common Stock Activity [Line Items]
Common stock dividends declared (in USD per share)	$ 0.825
Common stock special cash dividends per share declared (in usd per share)	$ 1

Stockholder's Equity - Schedule

Stockholder's Equity - Schedule of Common Stock Activity (Details) - shares		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Common Stock Activity [Roll Forward]
Beginning Balance (in shares)		585,521,512
Ending Balance (in shares)		588,396,757	585,521,512
Preferred stock, shares outstanding (in shares)		0
Common Shares, Issued
Common Stock Activity [Roll Forward]
Beginning Balance (in shares)		585,522,000	583,695,000	582,213,000
Common Stock Issued Under Stock-Based Compensation Plans (in shares)		2,674,000	1,511,000	1,482,000
Treasury Stock Purchased (1) (in shares)	[1]	0	0	0
Common Stock Issued Under Employee Stock Purchase Plan (in shares)		201,000	316,000	0
Treasury Stock Issued Under Stock-Based Compensation Plans (in shares)		0	0	0
Ending Balance (in shares)		588,397,000	585,522,000	583,695,000
Common Shares, Outstanding
Common Stock Activity [Roll Forward]
Beginning Balance (in shares)		585,265,000	583,571,000	581,914,000
Common Stock Issued Under Stock-Based Compensation Plans (in shares)		2,674,000	1,511,000	1,482,000
Treasury Stock Purchased (1) (in shares)	[1]	(997,000)	(504,000)	(389,000)
Common Stock Issued Under Employee Stock Purchase Plan (in shares)		201,000	316,000	377,000
Treasury Stock Issued Under Stock-Based Compensation Plans (in shares)		554,000	371,000	187,000
Ending Balance (in shares)		587,697,000	585,265,000	583,571,000
Common Stock Held In Treasury
Common Stock Activity [Roll Forward]
Beginning Balance (in shares)		257,000	124,000	299,000
Common Stock Issued Under Stock-Based Compensation Plans (in shares)		0	0	0
Treasury Stock Purchased (1) (in shares)	[1]	(997,000)	(504,000)	(389,000)
Common Stock Issued Under Employee Stock Purchase Plan (in shares)		0	0	377,000
Treasury Stock Issued Under Stock-Based Compensation Plans (in shares)		554,000	371,000	187,000
Ending Balance (in shares)		700,000	257,000	124,000
[1]Represents 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 SARs 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.

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ (12)
Other comprehensive (loss) income	4	$ 0	$ (7)
Ending balance	(8)	(12)
Significant amount reclassified out of AOCI	0	0	0
Foreign Currency Translation Adjustment
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(11)	(10)
Other comprehensive income (loss) before taxes	4	(1)
Tax effects	0	0
Other comprehensive (loss) income	4	(1)
Ending balance	(7)	(11)	(10)
Other
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(1)	(2)
Other comprehensive income (loss) before taxes	0	1
Tax effects	0	0
Other comprehensive (loss) income	0	1
Ending balance	(1)	(1)	(2)
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(12)	(12)
Other comprehensive income (loss) before taxes	4	0
Tax effects	0	0
Other comprehensive (loss) income	4	0	(7)
Ending balance	$ (8)	$ (12)	$ (12)

Other Income, Net (Details)

Other Income, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other Income and Expenses [Abstract]
Equity income (loss) from investments in Trinidad	$ 46	$ 18	$ (2)
Interest income	85	3	$ 12
Adjustment to deferred compensation expense	$ 15	$ 13

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Income Tax Assets (Liabilities), Net (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Deferred Income Tax Assets (Liabilities)
Foreign Oil and Gas Exploration and Development Costs Deducted for Tax Under Book Depreciation, Depletion and Amortization	$ (18)	$ (19)
Foreign Asset Retirement Obligations	81	51
Foreign Accrued Expenses and Liabilities	13	15
Foreign Net Operating Loss	82	80
Foreign Valuation Allowances	(116)	(111)
Foreign Other	(9)	(5)
Total Net Deferred Income Tax Assets	33	11
Deferred Income Tax (Assets) Liabilities
Oil and Gas Exploration and Development Costs Deducted for Tax Over Book Depreciation, Depletion and Amortization	5,291	5,063
Financial Commodity Derivative Contracts	(421)	(97)
Deferred Compensation Plans	(58)	(57)
Equity Awards	(60)	(86)
Other	(42)	(74)
Total Net Deferred Income Tax Liabilities	4,710	4,749
Total Net Deferred Income Tax Liabilities	$ 4,677	$ 4,738

Income Taxes - Schedule of Comp

Income Taxes - Schedule of Components of Income (Loss) Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Components Income (Loss) Before Income Taxes [Abstract]
United States	$ 9,752	$ 5,787	$ (756)
Foreign	149	146	17
Total	$ 9,901	$ 5,933	$ (739)

Income Taxes - Schedule of Co_2

Income Taxes - Schedule of Components of Income Tax Provision (Benefit) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Current:
Federal		$ 2,020	$ 1,203	$ (108)
State		126	85	7
Foreign		62	105	40
Total		2,208	1,393	(61)
Deferred:
Federal		(2)	(41)	(153)
State		(37)	(62)	(15)
Foreign		(22)	(19)	(18)
Total		(61)	(122)	(186)
Other Non-Current
Federal	[1]	0	0	113
Foreign		(5)	(2)	0
Total		(5)	(2)	113
Income Tax Provision (Benefit)		$ 2,142	$ 1,269	$ (134)
[1]Includes changes in certain amounts that are expected to be paid or received beyond the next twelve months. The primary component in 2020 is refundable alternative minimum tax (AMT) credits.

Income Taxes - Schedule of Tax

Income Taxes - Schedule of Tax Rate Reconciliation (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Federal Statutory and Effective Income Tax Rates [Abstract]
Statutory Federal Income Tax Rate	21%	21%	21%
State Income Tax, Net of Federal Benefit	0.70%	0.30%	0.90%
Income Tax Provision Related to Foreign Operations	0%	0.90%	(0.10%)
Income Tax Provision Related to Canadian Operations	0%	0%	(2.40%)
Stock-Based Compensation	0%	0.20%	(2.90%)
Other	0%	(1.00%)	1.70%
Effective Income Tax Rate	21.70%	21.40%	18.20%

Income Taxes - Schedule of Valu

Income Taxes - Schedule of Valuation Allowance (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Increase Decrease of Valuation of Allowance [Roll Forward]
Beginning Balance		$ 219	$ 219	$ 201
Increase	[1]	27	15	25
Decrease	[2]	(33)	(14)	(11)
Other	[3]	(6)	(1)	4
Ending Balance		$ 207	$ 219	$ 219
[1]Increase in valuation allowance related to the generation of tax NOLs and other deferred tax assets.[2]Decrease in valuation allowance associated with adjustments to certain deferred tax assets and their related allowances.[3]Represents dispositions, revisions and/or foreign exchange rate variances and the effect of statutory income tax rate changes.

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Income Tax Disclosure [Abstract]
Balance of state net operating loss expected to be carried forward	$ 2,200
Canadian Net operating loss carryforwards	$ 300

Employee Benefit Plans -Schedul

Employee Benefit Plans -Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expenses	$ 133	$ 152	$ 146
Lease and Well
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expenses	40	49	52
Gathering and Processing Costs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expenses	4	3	1
Exploration Costs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expenses	15	20	21
General and Administrative
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expenses	$ 74	$ 80	$ 72

Employee Benefit Plans - Narrat

Employee Benefit Plans - Narrative (Details) $ / shares in Units, $ in Millions		4 Months Ended	12 Months Ended
	Feb. 28, 2023 shares	Dec. 31, 2022 USD ($) $ / shares shares	Dec. 31, 2022 USD ($) awardPeriod $ / shares shares	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Aggregate maximum of common shares (in shares) | shares		20,000,000	20,000,000
Common shares available for grant(in shares) | shares		16,000,000	16,000,000
Net tax benefits / (deficiencies) recognized			$ 22	$ (11)	$ (22)
Stock-Based Compensation Expenses			133	152	146
Pension Plans
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total pension plan costs			56	52	46
Company contributions to foreign pension plans			1	1	1
Defined benefit plan, benefit obligation		$ 14	14	13
Fair value of foreign pension plan assets		15	15	14
(Prepaid) / Accrued benefit cost		$ (0.5)	$ (0.5)	(0.1)
Stock Options/SARs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Terms for stock options and SARs granted maximum			7 years
Stock-based compensation expense			$ 34	48	62
Stock options/SARs vested or expected to vest (in shares) | shares		4,100,000	4,100,000
Weighted average grant price vested or expected to vest (per share) | $ / shares		$ 77.85	$ 77.85
Intrinsic value of stock options/SARs vested or expected to vest		$ 211	$ 211
Weighted average remaining contractual life			4 years 1 month 6 days
Unrecognized compensation expense		$ 31	$ 31
Weighted average period over which unrecognized compensation expense will be recognized			1 year 4 months 24 days
ESPP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common shares available for grant(in shares) | shares		1,400,000	1,400,000
Percentage of fair market value at which employees may purchase company stock via the ESPP			85%
Contributions to the ESPP percentage			10%
ESPP | 2021 Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of award offerings | awardPeriod			2
ESPP offering period			6 months
Restricted Stock and Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense			$ 88	89	75
Unrecognized compensation expense		$ 285	$ 285
Weighted average period over which unrecognized compensation expense will be recognized			1 year 9 months 18 days
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 18	$ 18
Weighted average period over which unrecognized compensation expense will be recognized			1 year 9 months 18 days
Performance period for performance units		3 years	3 years
Minimum performance multiple at the completion performance period			0%
Maximum performance multiple at the completion performance period			200%
Stock-Based Compensation Expenses			$ 11	$ 15	$ 9
Performance multiple applied at the completion period						50%	125%	150%
Average Return on Capital Employed, Number of years			3 years
Maximum Performance Multiple at the Completion of the Performance Period Cap If TSR Is Negative			100%
Performance Units | Subsequent Event
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance multiple applied at the completion period	50%
Additional performance awards granted (in shares) | shares	86,076
Performance Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Modifier Applied To Performance Based Multiple			(70.00%)
Performance Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Modifier Applied To Performance Based Multiple			70%

Employee Benefit Plans- Schedul

Employee Benefit Plans- Schedule of Weighted Average Fair Values and Valuation Assumptions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock Options/SARs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Fair Value of Grants (in usd per share)	$ 28.30	$ 24.92	$ 11.06
Expected Volatility	42.20%	42.24%	44.47%
Risk-Free Interest Rate	0.89%	0.50%	0.21%
Dividend Yield	3.28%	2.26%	3.27%
Expected Life	5 years 3 months 18 days	5 years 2 months 12 days	5 years 2 months 12 days
ESPP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Fair Value of Grants (in usd per share)	$ 26.62	$ 18.12	$ 19.14
Expected Volatility	43%	51.27%	53.48%
Risk-Free Interest Rate	1.30%	0.07%	0.90%
Dividend Yield	2.89%	2.89%	2.27%
Expected Life	6 months	6 months	6 months

Employee Benefit Plans- Sched_2

Employee Benefit Plans- Schedule of Stock Options and SARs Transactions (Details) - Stock Options/SARs - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock Options and SARs Rollforward [Abstract]
Beginning balance (in shares)		9,969	10,186	9,395
Granted (in shares)		2	1,982	1,996
Exercised (in shares)	[1]	(5,526)	(1,130)	(23)
Forfeited (in shares)		(220)	(1,069)	(1,182)
Ending balance (in shares)		4,225	9,969	10,186
Vested or Expected to Vest (in shares)		2,462	6,197	6,343
Stock Options and SARs Rollforward [Abstract]
Beginning balance (in USD per share)		$ 84.37	$ 84.08	$ 94.53
Granted (in USD per share)		97.64	81.68	37.63
Exercised (in USD per share)	[1]	89.70	63.98	69.59
Forfeited (in USD per share)		82.74	98.15	88.93
Ending balance (in USD per share)		77.49	84.37	84.08
Vested or Expected to Vest (in USD per share)		$ 84.53	$ 95.33	$ 96.41
Intrinsic value of stock options/SARs exercised during the year		$ 190	$ 27	$ 0.4
[1]The total intrinsic value of stock options/SARs exercised during the years 2022, 2021 and 2020 was $190 million, $27 million and $0.4 million, respectively.  The intrinsic value is based upon the difference between the market price of the Common Stock on the date of exercise and the grant price of the stock options/SARs.

Employee Benefit Plans - Schedu

Employee Benefit Plans - Schedule of Stock Options and SARs Outstanding and Exercisable (Details) - Stock Options/SARs $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) $ / shares shares
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Stock Options and SARs Outstanding (in shares) | shares	4,225
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	4 years
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 77.49
Aggregate Intrinsic Value For Stock Options/SARs Outstanding | $	$ 220	[1]
Stock Options and SARs Exercisable (in shares) | shares	2,462
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	3 years
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 84.53
Aggregate Intrinsic Value For Stock Options/SARs Exercisable | $	$ 111	[1]
$ 34.00 to $ 52.99
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Range of Grant Prices Lower Limit (in USD per share)	$ 34
Range of Grant Prices Upper Range Limit (in USD per share)	$ 52.99
Stock Options and SARs Outstanding (in shares) | shares	1,029
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	4 years
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 37.52
Stock Options and SARs Exercisable (in shares) | shares	466
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	4 years
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 37.51
53.00 to     80.99
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Range of Grant Prices Lower Limit (in USD per share)	53
Range of Grant Prices Upper Range Limit (in USD per share)	$ 80.99
Stock Options and SARs Outstanding (in shares) | shares	593
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	3 years
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 74.98
Stock Options and SARs Exercisable (in shares) | shares	584
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	3 years
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 75.04
81.00 to     81.99
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Range of Grant Prices Lower Limit (in USD per share)	81
Range of Grant Prices Upper Range Limit (in USD per share)	$ 81.99
Stock Options and SARs Outstanding (in shares) | shares	1,513
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	6 years
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 81.81
Stock Options and SARs Exercisable (in shares) | shares	331
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	5 years
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 81.81
82.00 to     96.99
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Range of Grant Prices Lower Limit (in USD per share)	82
Range of Grant Prices Upper Range Limit (in USD per share)	$ 96.99
Stock Options and SARs Outstanding (in shares) | shares	562
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	1 year
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 95.62
Stock Options and SARs Exercisable (in shares) | shares	553
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	1 year
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 95.75
97.00 to   129.99
Summary Information By Grant Price Range For Stock Options And SARs Outstanding And Exercisable At End Of Period [Line Items]
Range of Grant Prices Lower Limit (in USD per share)	97
Range of Grant Prices Upper Range Limit (in USD per share)	$ 129.99
Stock Options and SARs Outstanding (in shares) | shares	528
Weighted Average Remaining Life for Stock Options/SARs Outstanding (Years)	3 years
Weighted Average Grant Price For Stock Options/SARs Outstanding (in usd per share)	$ 126.51
Stock Options and SARs Exercisable (in shares) | shares	528
Weighted Average Remaining Life For Stock Options/SARs Exercisable (Years)	3 years
Weighted Average Grant Price For Stock Options/SARs Exercisable (in usd per share)	$ 126.53
[1]Based upon the difference between the closing market price of the Common Stock on the last trading day of the year and the grant price of in-the-money stock options and SARs, in millions.

Employee Benefit Plans - Sche_2

Employee Benefit Plans - Schedule of ESPP Activity (Details) - ESPP shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($) participant shares	Dec. 31, 2021 USD ($) participant shares	Dec. 31, 2020 USD ($) participant shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Approximate Number of Participants | participant	1,969	2,036	2,063
Shares Purchased (in shares) | shares	201	316	377
Aggregate Purchase Price | $	$ 17,250	$ 17,224	$ 16,103

Employee Benefit Plans - Sche_3

Employee Benefit Plans - Schedule of Restricted Stock and Restricted Stock Unit Transactions (Details) - Restricted Stock and Restricted Stock Units - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Number of Shares and Units [Roll Forward]
Beginning balance (in shares)		4,680	[1]	4,742	[1]	4,546
Granted (in shares)		1,637		1,422		1,488
Released (in shares)	[2]	(2,019)		(1,388)		(1,213)
Forfeited (in shares)		(185)		(96)		(79)
Ending balance (in shares)	[1]	4,113		4,680		4,742
Weighted Average Grant Price Stock Option and SARs [Rollfoward]
Beginning balance (in USD per share)		$ 69.37	[1]	$ 74.97	[1]	$ 90.16
Granted (in USD per share)		113.21		81.50		38.10
Released (in USD per share)	[2]	81.76		101		85.92
Forfeited (in USD per share)		68.89		68.26		86.52
Ending balance (in USD per share)	[1]	$ 80.77		$ 69.37		$ 74.97
Intrinsic value of restricted stock and restricted stock units released during the years		$ 223		$ 110		$ 48
Aggregate intrinsic value of stock and unit outstanding		$ 533		$ 416		$ 236
[1]The total intrinsic value of restricted stock and restricted stock units outstanding at December 31, 2022, 2021 and 2020 was $533 million, $416 million and $236 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year.[2]The total intrinsic value of restricted stock and restricted stock units released during the years ended December 31, 2022, 2021 and 2020 was $223 million, $110 million and $48 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date restricted stock and restricted stock units are released.(2)

Employee Benefit Plans - Sche_4

Employee Benefit Plans - Schedule of Weighted Average Fair Values and Valuation Assumptions for Performance Units/Stocks (Details) - Performance Units - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Fair Value of Grants (in usd per share)	$ 126.55	$ 95.16	$ 42.77
Expected Volatility	56.11%	53.80%	47.27%
Risk-Free Interest Rate	4.01%	0.59%	0.16%

Employee Benefit Plans - Sche_5

Employee Benefit Plans - Schedule of Performance Unit and Performance Stock Transactions (Details) - Performance Units - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Number of Shares and Units [Roll Forward]
Beginning balance (in shares)		679,000	[1]	613,000	[1]	598,000
Granted (in shares)		122,000		222,000		172,000
Granted for Performance Multiple (in shares)	[2]	0		19,000		66,000
Released (in shares)	[3]	(57,000)		(175,000)		(223,000)
Forfeited (in shares)	[4]	(56,000)		0		0
Ending balance (in shares)	[1]	688,000	[5]	679,000		613,000
Weighted Average Grant Price Stock Option and SARs [Rollfoward]
Beginning balance (in USD per share)		$ 84.97	[1]	$ 88.38	[1]	$ 103.91
Granted (in USD per share)		126.55		95.16		42.77
Granted for Performance Multiple (in USD per share)	[2]	0		113.81		119.10
Released (in USD per share)	[3]	136.74		113.06		103.87
Forfeited (in USD per share)	[4]	136.74		0		0
Ending balance (in USD per share)	[1]	$ 83.82		$ 84.97		$ 88.38
Performance multiple applied at the completion period							50%	125%	150%
Intrinsic value of restricted stock and restricted stock units released during the years		$ 7		$ 13		$ 13
Aggregate intrinsic value of stock and unit outstanding		$ 89		$ 60		$ 31
Minimum performance units and stock allowed to be outstanding (in shares)		0
Maximum performance units and stock allowed to be outstanding (in shares)		1,376,000
[1]The total intrinsic value of Performance Units outstanding at December 31, 2022, 2021 and 2020 was $89 million, $60 million and $31 million, respectively. The intrinsic value is based on the closing market price of the Common Stock on the last trading day of the year.[2]Upon completion of the performance period for the Performance Units granted in 2017 and 2016, a performance multiple of 125% and 150%, respectively, was applied to each of the grants resulting in additional grants of Performance Units in February 2021 and 2020.[3]The total intrinsic value of Performance Units released during the years ended December 31, 2022, 2021 and 2020 was $7 million, $13 million and $13 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date 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.

Employee Benefit Plans - Sche_6

Employee Benefit Plans - Schedule of Vesting (Details)	12 Months Ended
	Dec. 31, 2022
Stock Options/SARs | Vesting Schedule - First Anniversary
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period increments	33.30%
Stock Options/SARs | Vesting Schedule - Second Anniversary
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period increments	33.30%
Stock Options/SARs | Vesting Schedule - Third Anniversary
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period increments	33.40%
Restricted Stock and Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based payment award, award vesting period	3 years
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cliff vesting period	3 years

Commitments and Contingencies_2

Commitments and Contingencies (Details)	Feb. 17, 2023 USD ($)	Dec. 31, 2022 USD ($) Bcfe MMBbls	Dec. 31, 2021 USD ($)
Subsequent Event [Line Items]
Standby letters of credit and guarantees outstanding		$ 776,000,000	$ 831,000,000
Total Minimum Commitments [Abstract]
2023		1,362,000,000
2024		1,149,000,000
2025		984,000,000
2026		791,000,000
2027		642,000,000
2028 and beyond		1,570,000,000
Total Minimum Commitments		$ 6,498,000,000
Oil and gas, delivery commitment, quantity committed, year 2023 | MMBbls		7
Oil and gas, delivery commitment, quantity committed, year 2024 | MMBbls		7
Oil and gas, delivery commitment, quantity committed, year 2025 | MMBbls		1
Natural gas, delivery commitment, quantity committed, year 2023 | Bcfe		347
Natural gas, delivery commitment, quantity committed, year 2024 | Bcfe		321
Natural gas, delivery commitment, quantity committed, year 2025 | Bcfe		277
Natural gas, delivery commitment, quantity committed, year 2026 | Bcfe		297
Natural gas, delivery commitment, quantity committed, year 2027 | Bcfe		293
Natural gas, delivery commitment, quantity committed, thereafter | Bcfe		3,540
Subsequent Event
Subsequent Event [Line Items]
Subsidiary guarantees demand for payment	$ 0

Net Income (Loss) Per Share - S

Net Income (Loss) Per Share - Schedule of Computation of Net Income Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Numerator for Basic and Diluted Earnings per Share -
Net income (loss) - basic	$ 7,759	$ 4,664	$ (605)
Net income (loss) - diluted	$ 7,759	$ 4,664	$ (605)
Denominator for Basic Earnings per Share -
Weighted average shares (in shares)	583	581	579
Denominator for Diluted Earnings per Share -
Adjusted diluted weighted average shares (in shares)	587	584	579
Net Income (Loss) Per Share
Basic ( in usd per share)	$ 13.31	$ 8.03	$ (1.04)
Diluted (in usd per share)	$ 13.22	$ 7.99	$ (1.04)
Stock Options/SARs
Potential Dilutive Common Shares -
Common shares attributable to dilutive effect of share-based payment arrangements (in shares)	2	0	0
Restricted Stock/Units and Performance Units
Potential Dilutive Common Shares -
Common shares attributable to dilutive effect of share-based payment arrangements (in shares)	2	3	0

Net Income (Loss) Per Share - N

Net Income (Loss) Per Share - Narrative (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock Options/SARs
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount ( in shares)	1	6	10
Restricted Stock/Units and Performance Units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, amount ( in shares)			5

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Schedule of Computation of Net Income Per Share (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Supplemental Cash Flow Information [Abstract]
Interest, Net of Capitalized Interest	$ 173	$ 185	$ 205
Income Taxes, Net of Refunds Received	$ 2,475	$ 1,114	$ (206)

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Equity [Abstract]
Accrued capital expenditures	$ 713	$ 592	$ 414
Non-cash property exchanges	$ 153	50	212
Noncash additions to other property, plant and equipment		$ 74	$ 174

Business Segment Information -

Business Segment Information - Narrative (Details)	12 Months Ended
	Dec. 31, 2022 Segment
Segment Reporting [Abstract]
Number of operating segments	1

Business Segment Information _2

Business Segment Information - Schedule of Selected Financial Information by Reportable Segment (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Jun. 30, 2021	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Schedule of Segment Reporting Information By Segment [Abstract]
Gains (Losses) on Asset Dispositions, Net			$ 74		$ 17		$ (47)
Operating Revenues and Other			25,702	[1]	18,642	[2]	11,032	[3]
Depreciation, Depletion and Amortization			3,542		3,651		3,400
Operating Income (Loss)			9,966	[4]	6,102	[5]	(544)	[6]
Interest Income			85		3		12
Other Income (Expense)			29		6		(2)
Net Interest Expense (Income)			179		178		205
Income (Loss) Before Income Taxes			9,901		5,933		(739)
Income Tax Provision (Benefit)			2,142		1,269		(134)
Additions to Oil and Gas Properties, Excluding Dry Hole Costs			4,727		3,617
Total Property, Plant and Equipment, Net			29,429		28,426
Total Assets			41,371		38,236
Dry Hole Costs			45		71		13
Crude Oil and Condensate
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			16,367		11,125		5,786
Natural Gas Liquids
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			2,648		1,812		668
Natural Gas
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			3,781		2,444		837
Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			(3,982)		(1,152)		1,145
Gathering, Processing and Marketing
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			6,696		4,288		2,583
Other, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			118		108		60
United States
Schedule of Segment Reporting Information By Segment [Abstract]
Gains (Losses) on Asset Dispositions, Net			77		(40)		(47)
Operating Revenues and Other			25,394	[1]	18,265	[2]	10,795	[3]
Depreciation, Depletion and Amortization			3,469		3,558		3,324
Operating Income (Loss)			9,880	[4]	6,013	[5]	(546)	[6]
Interest Income			81		3		11
Other Income (Expense)			(17)		(14)		0
Net Interest Expense (Income)			179		178		205
Income (Loss) Before Income Taxes			9,765		5,824		(740)
Income Tax Provision (Benefit)			2,106		1,247		(157)
Additions to Oil and Gas Properties, Excluding Dry Hole Costs			4,599		3,557
Total Property, Plant and Equipment, Net			29,109		28,213
Total Assets			40,349		37,436
Amount of sales with a single significant purchaser in the United States segment			3,300		2,700		1,100
Amount of sales with a second significant purchaser in the United States segment.			3,100		2,600
Amount of sales with a third significant purchaser in the United States segment.			3,000
Pretax impairment charges							1,570
Pretax impairment charges For other assets							228
United States | Crude Oil and Condensate
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			16,349		11,094		5,774
United States | Natural Gas Liquids
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			2,648		1,812		668
United States | Natural Gas
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			3,489		2,156		614
United States | Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			(3,982)		(1,152)		1,145
United States | Gathering, Processing and Marketing
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			6,695		4,287		2,581
United States | Other, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			118		108		60
Trinidad
Schedule of Segment Reporting Information By Segment [Abstract]
Gains (Losses) on Asset Dispositions, Net			(4)		(2)		0
Operating Revenues and Other			307	[1]	300	[2]	182	[3]
Depreciation, Depletion and Amortization			73		87		60
Operating Income (Loss)			122	[4]	151	[5]	75	[6]
Interest Income			2		0		1
Other Income (Expense)			46		8		(2)
Net Interest Expense (Income)			0		0		0
Income (Loss) Before Income Taxes			170		159		74
Income Tax Provision (Benefit)			35		66		15
Additions to Oil and Gas Properties, Excluding Dry Hole Costs			122		55
Total Property, Plant and Equipment, Net			307		204
Total Assets			879		637
Trinidad | Crude Oil and Condensate
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			18		31		11
Trinidad | Natural Gas Liquids
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			0		0		0
Trinidad | Natural Gas
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			292		270		169
Trinidad | Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			0		0		0
Trinidad | Gathering, Processing and Marketing
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer			1		1		2
Trinidad | Other, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer			0		0		0
Other International
Schedule of Segment Reporting Information By Segment [Abstract]
Gains (Losses) on Asset Dispositions, Net		$ 58	1	[7]	59	[7]	0	[7]
Operating Revenues and Other	[7]		1	[1]	77	[2]	55	[3]
Depreciation, Depletion and Amortization	[7]		0		6		16
Operating Income (Loss)	[7]		(36)	[4]	(62)	[5]	(73)	[6]
Interest Income	[7]		2		0		0
Other Income (Expense)	[7]		0		12		0
Net Interest Expense (Income)	[7]		0		0		0
Income (Loss) Before Income Taxes	[7]		(34)		(50)		(73)
Income Tax Provision (Benefit)	[7]		1		(44)		8
Additions to Oil and Gas Properties, Excluding Dry Hole Costs	[7]		6		5
Total Property, Plant and Equipment, Net	[7]		13		9
Total Assets	[7]		143		163
Pretax impairment charges			15		45		81
Dry Hole Costs					42
Other International | Crude Oil and Condensate
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer	[7]		0		0		1
Other International | Natural Gas Liquids
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer	[7]		0		0		0
Other International | Natural Gas
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer	[7]		0		18		54
Other International | Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer	[7]		0		0		0
Other International | Gathering, Processing and Marketing
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue from contract with customer	[7]		0		0		0
Other International | Other, Net
Schedule of Segment Reporting Information By Segment [Abstract]
Revenue not from contract with customer	[7]		$ 0		$ 0		$ 0
[1]EOG had sales activity with three significant purchasers in 2022, one totaling $3.3 billion, another totaling $3.1 billion and a third totaling $3.0 billion of consolidated Operating Revenues and Other in the United States segment.[2]EOG had sales activity with two significant purchasers in 2021, one totaling $2.7 billion and the other totaling $2.6 billion of consolidated Operating Revenues and Other in the United States segment.[3]EOG had sales activity with three significant purchasers in 2020, each totaling $1.1 billion of consolidated Operating Revenues and Other in the United States segment.[4]EOG recorded pretax impairment charges of $15 million in 2022 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Note 14.[5]EOG recorded pretax impairment charges of $45 million and dry hole costs of $42 million in 2021 in the Other International segment related to its decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. In addition, EOG recorded net gains of asset dispositions of $58 million in 2021 in the Other International segment during the second quarter of 2021 due to the sale of its China operations. See Notes 14 and 17, respectively.[6]EOG recorded pretax impairment charges of $1,570 million in 2020 for proved oil and gas properties, leasehold costs and other assets due to the decline in commodity prices and revisions of asset retirement obligations for certain properties in the United States segment. In addition, EOG recorded pretax impairment charges of $228 million in 2020 for owned and leased sand and crude-by-rail assets, also in the United States segment. EOG recorded pretax impairment charges of $81 million in 2020 for proved oil and gas properties and firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada, in the Other International segment. See Notes 13 and 14.[7]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.

Risk Management Activities - Na

Risk Management Activities - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Unrealized gain (loss) on derivatives and commodity contracts	$ (3,982)	$ (1,152)	$ 1,145
Cash received from (payments for) settlements of crude oil	$ (3,501)	$ (638)	$ 1,071
Receivable major customer percentage	10%	10%
Collateral already posted on derivative	$ 324	$ 140
Collateral held on derivative	$ 0	$ 0

Risk Management Activities - Sc

Risk Management Activities - Schedule of Derivative Instruments (Details) $ in Millions		3 Months Ended		12 Months Ended
		Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2022 BTU $ / bbl bbl
Crude Oil | Price Swaps
Derivatives, Fair Value [Line Items]
Cash paid for settlement of contracts | $		$ 63	$ 593
Crude Oil | Derivative Contracts - January through March (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				140
Weighted Average Price Differential ($/MMBtu)(in usd per share)				65.58
Crude Oil | OffSetting Derivative Contracts - January through March (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - April through June (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				140
Weighted Average Price Differential ($/MMBtu)(in usd per share)				65.62
Crude Oil | Offsetting Derivative Contracts - April through June (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - July through September | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				140
Weighted Average Price Differential ($/MMBtu)(in usd per share)				65.59
Crude Oil | OffSetting Derivative Contracts - July through September | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - October through December (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				53
Weighted Average Price Differential ($/MMBtu)(in usd per share)				66.11
Crude Oil | OffSetting Derivative Contracts - October through December (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - October through December | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				87
Weighted Average Price Differential ($/MMBtu)(in usd per share)				65.41
Crude Oil | OffSetting Derivative Contracts - October and December | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				87
Weighted Average Price Differential ($/MMBtu)(in usd per share)				88.85
Crude Oil | Derivative Contracts - January through March (closed) Year Two | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				55
Weighted Average Price Differential ($/MMBtu)(in usd per share)				67.96
Crude Oil | Offsetting Derivative Contracts - January through March (closed) Year Two | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - January through March | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				95
Weighted Average Price Differential ($/MMBtu)(in usd per share)				67.90
Crude Oil | OffSetting Derivative Contracts - January Through March | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				6
Weighted Average Price Differential ($/MMBtu)(in usd per share)				102.26
Crude Oil | Derivative Contracts - April Through May (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				29
Weighted Average Price Differential ($/MMBtu)(in usd per share)				68.28
Crude Oil | offsetting Derivative Contracts - April Through May (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - April Through May | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				91
Weighted Average Price Differential ($/MMBtu)(in usd per share)				67.63
Crude Oil | offsetting Derivative Contracts - April Through May | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				2
Weighted Average Price Differential ($/MMBtu)(in usd per share)				98.15
Crude Oil | Derivative Contracts - June (CLosed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				118
Weighted Average Price Differential ($/MMBtu)(in usd per share)				67.77
Crude Oil | OffSetting Derivative Contracts - June (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - June | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				2
Weighted Average Price Differential ($/MMBtu)(in usd per share)				69.10
Crude Oil | OffSetting Derivative Contracts - June | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				2
Weighted Average Price Differential ($/MMBtu)(in usd per share)				98.15
Crude Oil | Derivative Contracts - July through September (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				100
Weighted Average Price Differential ($/MMBtu)(in usd per share)				70.15
Crude Oil | Offsetting Derivative Contracts - July Through September (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - October through December - Year Two (Closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				69
Weighted Average Price Differential ($/MMBtu)(in usd per share)				69.41
Crude Oil | Offsetting Derivative Contracts - October through December - Year Two | Price Swaps
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl				0
Weighted Average Price Differential ($/MMBtu)(in usd per share)				0
Crude Oil | Derivative Contracts - January through December (closed) | Roll Differential Swap
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl	[1]			125
Weighted Average Price Differential ($/MMBtu)(in usd per share)	[1]			0.15
Natural Gas | Price Swaps
Derivatives, Fair Value [Line Items]
Cash paid for settlement of contracts | $			$ 735
Natural Gas | Derivative Contracts - October through December (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.05
Volume (MMBTU) | BTU				425
Natural Gas | Derivative Contracts - October through December | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				4.32
Volume (MMBTU) | BTU				300
Natural Gas | Derivative Contracts - January through December (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.05
Volume (MMBTU) | BTU				425
Natural Gas | Derivative Contracts - January (closed) | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.36
Volume (MMBTU) | BTU				300
Natural Gas | Derivative Contracts - February Through December | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.36
Volume (MMBTU) | BTU				300
Natural Gas | Derivative Contracts - January Through September | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.57
Volume (MMBTU) | BTU				725
Natural Gas | Derivative Contracts - Year Two - January through December | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.07
Volume (MMBTU) | BTU				725
Natural Gas | Derivative Contracts - Year Two - January through December | HSC Differential Basis Swaps
Derivatives, Fair Value [Line Items]
Volume (MMBTU) | BTU	[2]			210
Weighted Average Price (MMBtu) ( in usd per share)	[2]			0.01
Natural Gas | Derivative Contracts - Year Three - January through December | Price Swaps
Derivatives, Fair Value [Line Items]
Weighted Average Price Differential ($/MMBtu)(in usd per share)				3.07
Volume (MMBTU) | BTU				725
Natural Gas | Derivative Contracts - Year Three - January through December | HSC Differential Basis Swaps
Derivatives, Fair Value [Line Items]
Volume (MMBTU) | BTU	[2]			135
Weighted Average Price (MMBtu) ( in usd per share)	[2]			0.01
Natural Gas | Derivative Contracts - Year Four - January through December | HSC Differential Basis Swaps
Derivatives, Fair Value [Line Items]
Volume (MMBTU) | BTU	[2]			10
Weighted Average Price (MMBtu) ( in usd per share)	[2]			0
Natural Gas | Derivative Contracts - Year Five - January through December | HSC Differential Basis Swaps
Derivatives, Fair Value [Line Items]
Volume (MMBTU) | BTU	[2]			10
Weighted Average Price (MMBtu) ( in usd per share)	[2]			0
[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.[2]This settlement index is used to fix the differential between pricing at the Houston Ship Channel and NYMEX Henry Hub prices.

Risk Management Activities - _2

Risk Management Activities - Schedule of Derivative Instruments In Statement Of Financial Position, Fair Value (Details) - USD ($)		Dec. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Liabilities from Price Risk Management Activities		$ 169,000,000	$ 269,000,000
Price Risk Derivative
Derivatives, Fair Value [Line Items]
Other Assets		0	6,000,000
Liabilities from Price Risk Management Activities	[1]	169,000,000	269,000,000
Other Liabilities	[2]	371,000,000	$ 37,000,000
Liabilities From Price Risk Management Activities
Derivatives, Fair Value [Line Items]
Derivative gross liability		287,000,000
Derivative , gross asset		26,000,000
Collateral posted on derivative		92,000,000
Other Liabilities
Derivatives, Fair Value [Line Items]
Derivative gross liability		606,000,000
Derivative , gross asset		3,000,000
Collateral posted on derivative		$ 232,000,000
[1]The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $287 million, partially offset by gross assets of $26 million and collateral posted with counterparties of $92 million, at December 31, 2022.[2]The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $606 million, partially offset by gross assets of $3 million and collateral posted with counterparties of $232 million, at December 31, 2022.

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis (Details) - Commodity Contract - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Natural Gas | Price Swaps
Financial Assets:
Assets, fair value disclosure		$ 29
Financial Liabilities:
Liabilities, fair value disclosure	$ 703	121
Natural Gas | Price Swaps | Quoted Prices in Active Markets (Level 1)
Financial Assets:
Assets, fair value disclosure		0
Financial Liabilities:
Liabilities, fair value disclosure	0	0
Natural Gas | Price Swaps | Significant Other Observable Inputs (Level 2)
Financial Assets:
Assets, fair value disclosure		29
Financial Liabilities:
Liabilities, fair value disclosure	703	121
Natural Gas | Price Swaps | Significant Unobservable Inputs (Level 3)
Financial Assets:
Assets, fair value disclosure		0
Financial Liabilities:
Liabilities, fair value disclosure	0	0
Natural Gas | Basis Swaps
Financial Assets:
Assets, fair value disclosure	29	2
Financial Liabilities:
Liabilities, fair value disclosure		1
Natural Gas | Basis Swaps | Quoted Prices in Active Markets (Level 1)
Financial Assets:
Assets, fair value disclosure	0	0
Financial Liabilities:
Liabilities, fair value disclosure		0
Natural Gas | Basis Swaps | Significant Other Observable Inputs (Level 2)
Financial Assets:
Assets, fair value disclosure	29	2
Financial Liabilities:
Liabilities, fair value disclosure		1
Natural Gas | Basis Swaps | Significant Unobservable Inputs (Level 3)
Financial Assets:
Assets, fair value disclosure	0	0
Financial Liabilities:
Liabilities, fair value disclosure		0
Crude Oil | Price Swaps
Financial Assets:
Assets, fair value disclosure		15
Financial Liabilities:
Liabilities, fair value disclosure	190	340
Crude Oil | Price Swaps | Quoted Prices in Active Markets (Level 1)
Financial Assets:
Assets, fair value disclosure		0
Financial Liabilities:
Liabilities, fair value disclosure	0	0
Crude Oil | Price Swaps | Significant Other Observable Inputs (Level 2)
Financial Assets:
Assets, fair value disclosure		15
Financial Liabilities:
Liabilities, fair value disclosure	190	340
Crude Oil | Price Swaps | Significant Unobservable Inputs (Level 3)
Financial Assets:
Assets, fair value disclosure		0
Financial Liabilities:
Liabilities, fair value disclosure	$ 0	0
Crude Oil | Roll Differential Swap
Financial Liabilities:
Liabilities, fair value disclosure		24
Crude Oil | Roll Differential Swap | Quoted Prices in Active Markets (Level 1)
Financial Liabilities:
Liabilities, fair value disclosure		0
Crude Oil | Roll Differential Swap | Significant Other Observable Inputs (Level 2)
Financial Liabilities:
Liabilities, fair value disclosure		24
Crude Oil | Roll Differential Swap | Significant Unobservable Inputs (Level 3)
Financial Liabilities:
Liabilities, fair value disclosure		$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Proved Oil and Gas Properties, Other Property, Plant and Equipment and Other Assets [Abstract]
Proved oil and gas properties carrying amount	$ 146	$ 27	$ 1,587
Assets written down during the period - fair value at end of period	26	7	319
Pretax impairment charges	120	20	1,268
Pretax impairment charge for a commodity price-related write-down			$ 72
Debt Disclosure [Abstract]
Aggregate principal amount of current and long-term debt	4,890	4,890
Estimated fair value of debt	$ 4,740	$ 5,577

Impairment Expense - Schedule o

Impairment Expense - Schedule of Impairment Expenses (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties		$ 382	$ 376	$ 2,100
Proved Properties
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties	[1]	120	20	1,268
Unproved Properties
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties	[2]	206	310	472
Impairments of unproved oil and gas properties				252
Impairment of oil and gas properties due to exit activities			38
Other Assets
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties	[3]	29	28	300
Impairments for owned and leased sand and crude-by-rail assets				228
Other assets impairments related to commodity price-related write-down				72
Inventories
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties		25	13	0
Firm Commitments Contracts
Impairment of Oil and Gas Properties [Line Items]
Impairment of oil and gas properties	[4]	$ 2	$ 5	60
Canadian firm commitment contracts				$ 60
[1]Impairments to proved oil and gas properties in 2020 included legacy and non-core natural gas and crude oil and combo plays. See Notes 1 and 13.[2]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. Impairments of unproved oil and gas properties included $38 million in 2021 for the decision in the fourth quarter of 2021 to exit Block 36 and Block 49 in Oman. Impairments of unproved oil and gas properties included charges of $252 million in 2020 for certain leasehold costs that are no longer expected to be developed before expiration in the United States. See Note 1.[3]Includes impairment charges for owned and leased sand and crude-by-rail assets of $228 million in 2020 (see Note 18) and a commodity price-related write-down of other assets of $72 million in 2020 (see Note 13).[4]Includes impairment charges of $60 million in 2020 for firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Carrying Amount at Beginning of Period		$ 1,231	$ 1,217
Liabilities Incurred		100	81
Liabilities Settled	[1]	(215)	(131)
Accretion		43	44
Revisions		173	20
Foreign Currency Translations		(4)	0
Carrying Amount at End of Period		1,328	1,231
Current Portion		38	43
Noncurrent Portion		$ 1,290	$ 1,188
[1]Includes settlements related to asset sales and property exchanges.

Exploratory Well Costs (Details

Exploratory Well Costs (Details) $ in Millions		12 Months Ended
		Dec. 31, 2022 USD ($) well	Dec. 31, 2021 USD ($) well	Dec. 31, 2020 USD ($) well
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Beginning balance		$ 7	$ 29	$ 26
Additions Pending the Determination of Proved Reserves		135	73	108
Reclassifications to Proved Properties		(88)	(41)	(81)
Costs Charged to Expense	[1]	(39)	(54)	(24)
Ending balance		15	7	29
Capitalized exploratory well costs that have been capitalized for a period of one year or less		15	7	26
Capitalized exploratory well costs that have been capitalized for a period greater than one year		$ 0	$ 0	$ 3	[2]
Number of exploratory wells that have been capitalized for a period greater than one year | well		0	0	1
[1]Includes capitalized exploratory well costs charged to either dry hole costs or impairments.[2](1)    Consists of costs related to a project in the United States at December 31, 2020.

Acquisitions and Divestitures (

Acquisitions and Divestitures (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Business Combination, Separately Recognized Transactions [Line Items]
Gains (losses) on asset dispositions, net	$ 74	$ 17	$ (47)
Proceeds on asset dispositions	349	231	192
United States
Business Combination, Separately Recognized Transactions [Line Items]
Payments to acquire oil and gas property	$ 393	95	82
Other International
Business Combination, Separately Recognized Transactions [Line Items]
Payments to acquire oil and gas property			$ 38
Held-for-sale
Business Combination, Separately Recognized Transactions [Line Items]
Book value of assets held-for-sale		99
Book value of asset retirement obligations		$ 105

Leases - Schedule of Lease (Det

Leases - Schedule of Lease (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating Lease Cost	[1]	$ 282	$ 295	$ 393
Amortization of Lease Assets		36	39	21
Interest on Lease Liabilities		6	7	4
Variable Lease Cost		71	63	91
Short-Term Lease Cost		425	257	194
Total Lease Cost		$ 820	$ 661	703
Operating lease, impairment expense				$ 35
[1]Operating lease cost includes impairment expenses of $35 million in 2020.

Leases - Schedule of Outstandin

Leases - Schedule of Outstanding Lease Assets And Lease Liabilities (Details) - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Operating and Finance Leases [Line Items]
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		Other Assets, Noncurrent	Other Assets, Noncurrent
Other Assets		$ 846	$ 743
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		Property, Plant and Equipment, Gross	Property, Plant and Equipment, Gross
Property, Plant and Equipment, Net	[1]	$ 203	$ 241
Total		$ 1,049	$ 984
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Current Portion of Operating Lease Liabilities	Current Portion of Operating Lease Liabilities
Current Portion of Operating Lease Liabilities		$ 296	$ 240
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Current Portion of Long-Term Debt	Current Portion of Long-Term Debt
Current Portion of Long-Term Debt		$ 33	$ 37
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other Liabilities	Other Liabilities
Other Liabilities		$ 584	$ 558
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Long-Term Debt	Long-Term Debt
Long-Term Debt		$ 182	$ 213
Total		1,095	1,048
Property, Plant and Equipment
Operating and Finance Leases [Line Items]
Finance lease, accumulated amortization		$ 157	$ 119
[1]Finance lease assets are recorded net of accumulated amortization of $157 million and $119 million at December 31, 2022 and 2021, respectively.

Leases - Schedule of Weighted A

Leases - Schedule of Weighted Average Remaining Lease Term And Discount Rate (Details)	Dec. 31, 2022	Dec. 31, 2021
Weighted Average Remaining Lease Term (in years):
Operating Leases	4 years 10 months 24 days	5 years 3 months 18 days
Finance Leases	6 years 6 months	7 years
Weighted Average Discount Rate:
Operating Leases	3.40%	3%
Finance Leases	2.60%	2.60%

Leases - Schedule of Cash Paid

Leases - Schedule of Cash Paid for Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating and Finance Leases [Line Items]
Repayment of Finance Lease Liabilities	$ 35	$ 37	$ 19
Operating Activities
Operating and Finance Leases [Line Items]
Repayment of Operating Lease Liabilities Associated with Operating Activities and Investing Activities	199	207	223
Investing Activities
Operating and Finance Leases [Line Items]
Repayment of Operating Lease Liabilities Associated with Operating Activities and Investing Activities	$ 95	$ 98	$ 130

Leases - Narrative (Details)

Leases - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating leases non-cash leasing activities	$ 511	$ 333	$ 893
Finance leases non-Cash leasing activities	0	$ 74	$ 174
Leases not yet commenced	$ 622
Minimum commenced lease term	1 year
Maximum commenced lease term	15 years

Leases - Schedule of Operating

Leases - Schedule of Operating And Finance Non-Cancellable Leases Maturity (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Leases, Operating [Abstract]
2023	$ 323
2024	213
2025	106
2026	80
2027	70
2028 and Beyond	172
Total Lease Payments	964
Less: Discount to Present Value	84
Total Lease Liabilities	880
Current Portion of Operating Lease Liabilities	296	$ 240
Long-Term Lease Liabilities	584	558
Finance Lease, Liability [Abstract]
2023	37
2024	37
2025	36
2026	30
2027	30
2028 and Beyond	65
Total Lease Payments	235
Less: Discount to Present Value	20
Total Lease Liabilities	215	250
Current Portion of Long-Term Debt	33	37
Long-Term Debt	$ 182	$ 213