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美國

證券交易委員會

華盛頓特區20549

格式			10-Q

（標記一）

☒           根據1934年證券交易法第13或15(d)節的季度報告

截至季度結束日期的財務報告2024年9月30日

or

☐          根據1934年證券交易法第13或15(d)節的轉型報告書

委託文件編號：001-398661-9743

 

EOG RESOURCES, INC.

（按章程規定的註冊人確切名稱）

特拉華州						47-0684736
(所在州或其他司法管轄區) 註冊認證）						（聯邦稅號 唯一識別號碼）

1111 Bagby, Sky Lobby 2, 休斯頓, 得克薩斯州 77002

(主要行政辦公地址) (郵政編碼)

713-651-7000

（註冊人的電話號碼，包括區號）

根據法案第12（b）條註冊的證券：

每一類的名稱			交易標的			在其上註冊的交易所的名稱
普通股，每股面值0.01美元			EOG。			請使用moomoo賬號登錄查看New York Stock Exchange

請勾選相應項目表示公司已根據《1934年證券交易法》第13或15(d)條規定在過去12個月內（或更短期限）內報告了所有必需報告，並在過去90天內一直受到此類報告要求。Yes ☒  否☐

請勾選以下方框，指示註冊者是否在過去的12個月內（或更短時間段內，註冊者按規定需要提交此類文件的期間）已提交每份互動數據文件，以執行《S-t條例》第405條規定。Yes ☒ 否☐

請在複選框中標記，指示註冊申請人是否爲大型快速文件者、快速文件者、非快速文件者、較小報告公司或新興成長企業。請參閱《交易所法》第120億.2條中"大型快速文件者"、"快速文件者"、"較小報告公司"和"新興成長企業"的定義。

大型加速報告人 ☒ 加速歸檔人☐ 非加速歸檔人☐

小型報表公司 ☐ 新興增長型公司 ☐

如果公司無法符合證券交易法第13(a)條規定，使用延長過渡期來遵守任何新的或修訂的財務會計準則，請在複選框中指示。 ☐

用複選標記表示，報告人是否爲殼公司（如《交易所法》第120億.2條所定義）。

是☐ 否☒

指明截至最近可獲得日期時，每個註冊人的普通股類別的流通股數。

每一類的名稱						股數
普通股，每股面值0.01美元						562,450,411			（截至2024年10月30日）

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EOG RESOURCES, INC.

目錄

第I部分			財務信息						頁碼。
			項目1。			基本報表(未經審計)
						控件據財務報表和綜合收益 - 截至2024年9月和2023年的三個月和九個月			3
						基本報表 - 2024年9月30日和2023年12月31日			4
						控件據股東權益 - 截至2024年9月和2023年的三個月和九個月			5
						2024年9月30日和2023年止九個月的簡明合併現金流量表			7
						簡明合併財務報表註釋			8
			ITEm 2.			管理層對財務狀況和經營結果的討論和分析			21
			項目3。			有關市場風險的定量和定性披露			40
			項目4。			控制和程序			40
第二部分			其他信息
			項目1。			法律訴訟			41
			ITEm 2.			未註冊的股票股權銷售和籌款用途			41
			第5項			其他信息			42
			項目6。			展示資料			43
簽名									45

-2-

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第一部分. 財務信息

項目1。基本報表

EOG RESOURCES, INC.

綜合利潤和綜合收益的簡明綜合利潤表

（以百萬爲單位，除每股數據外）

(未經審計)

			三個月結束 9月30日,												九個月結束 9月30日,
			2024						2023						2024						2023
營業收入和其他
wti原油和凝析油			$	3,488					$	3,717					$	10,660					$	10,151
天然氣液體			524						501						1,552						1,400
天然氣			372						417						1,057						1,268
標記到市場金融商品和其他衍生合約的收益			79						43						269						520
採集、處理和營銷			1,481						1,478						4,459						4,333
資產處置淨收益（淨虧損）			(7)						35						39						95
其他，淨額			28						21						77						62
總計			5,965						6,212						18,113						17,829
研究和開發
租賃和井			392						369						1,178						1,076
採集、處理和運輸成本			445						406						1,281						1,197
勘探成本			43						43						122						140
乾井成本			—						—						6						1
減值			15						54						115						123
營銷成本			1,500						1,383						4,394						4,200
折舊、枯竭和攤銷			1,031						898						3,089						2,562
一般和行政			167						161						480						448
除所得稅外的稅金			283						341						958						983
總計			3,876						3,655						11,623						10,730
營業收入			2,089						2,557						6,490						7,099
其他收入，淨額			76						52						204						168
利息支出和所得稅前收入			2,165						2,609						6,694						7,267
利息支出，淨額			31						36						100						113
稅前利潤			2,134						2,573						6,594						7,154
所得稅費用			461						543						1,442						1,548
淨利潤			$	1,673					$	2,030					$	5,152					$	5,606
每股淨利潤
基本			$	2.97					$	3.51					$	9.05					$	9.65
攤薄			$	2.95					$	3.48					$	8.99					$	9.60
普通股平均數量
基本			564						579						569						581
攤薄			568						583						573						584
綜合收益
淨利潤			$	1,673					$	2,030					$	5,152					$	5,606
其他綜合收益（損失）
外幣翻譯調整			(1)						2						—						1
其他綜合收益（損失）			(1)						2						—						1
綜合收益			$	1,672					$	2,032					$	5,152					$	5,607

隨附說明是這些簡明合併財務報表的一部分。

-3-

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EOG RESOURCES, INC.

簡明合併資產負債表

(以百萬爲單位，除股票數據外)

(未經審計)

			9月30日, 2024						12月31日, 2023
資產
流動資產
現金及現金等價物			$	6,122					$	5,278
應收賬款淨額			2,545						2,716
存貨			1,038						1,275
價格風險管理活動資產			—						106
應收所得稅			2						—
其他			458						560
總計			10,165						9,935
固定資產
石油和天然氣資產（成功探明方法）			75,887						72,090
其他物業、廠房和設備			6,314						5,497
資產、廠房及設備總計			82,201						77,587
減：累積折舊、減值和攤銷			(48,075)						(45,290)
總資產、廠房和設備，已扣除折舊淨額			34,126						32,297
遞延所得稅負債			42						42
其他資產			1,818						1,583
總資產			$	46,151					$	43,857
負債和股東權益
流動負債
應付賬款			$	2,290					$	2,437
待支付的應計稅款			855						466
未付股息			513						526
價格風險管理活動中的負債			32						—
短期借款			34						34
經營租賃負債的流動部分			338						325
其他			344						286
總計			4,406						4,074
長期債務			3,742						3,765
其他負債			2,480						2,526
遞延所得稅			5,949						5,402
承諾和事項（注8）
股東權益
普通股，$0.01 面值， 1,280,000,000 授權股數和 588,843,718 2024年9月30日被授權的股份和 588,748,473 2023年12月31日發行的股份			206						206
超額實收資本			6,058						6,166
累計其他綜合損失			(9)						(9)
未分配利潤			26,231						22,634
在庫存中持有的普通股， 24,125,378 2024年9月30日的股票和 7,888,105 2023年12月31日的股票			(2,912)						(907)
股東權益總計			29,574						28,090
負債和股東權益總計			$	46,151					$	43,857

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

-4-

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EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Millions, Except Per Share Data)

(Unaudited)

			Common Stock						Additional Paid In Capital						Accumulated Other Comprehensive Loss						Retained Earnings						Common Stock Held In Treasury						Total Stockholders' Equity
Balance at June 30, 2024			$	206					$	6,219					$	(8)					$	25,071					$	(2,329)					$	29,159
Net Income			—						—						—						1,673						—						1,673
Common Stock Dividends Declared, $0.91 Per Share			—						—						—						(513)						—						(513)
Other Comprehensive Loss			—						—						(1)						—						—						(1)
Restricted Stock and Restricted Stock Units, Net			—						(208)						—						—						208						—
Stock-Based Compensation Expenses			—						58						—						—						—						58
Treasury Stock Repurchased			—						—						—						—						(765)						(765)
Change in Treasury Stock - Stock Compensation Plans, Net			—						(11)						—						—						(26)						(37)
Balance at September 30, 2024			$	206					$	6,058					$	(9)					$	26,231					$	(2,912)					$	29,574

			Common Stock						Additional Paid In Capital						Accumulated Other Comprehensive Loss						Retained Earnings						Common Stock Held In Treasury						Total Stockholders' Equity
Balance at June 30, 2023			$	206					$	6,257					$	(9)					$	20,497					$	(694)					$	26,257
Net Income			—						—						—						2,030						—						2,030
Common Stock Dividends Declared, $0.825 Per Share			—						—						—						(480)						—						(480)
Other Comprehensive Income			—						—						2						—						—						2
Restricted Stock and Restricted Stock Units, Net			—						(154)						—						—						154						—
Stock-Based Compensation Expenses			—						57						—						—						—						57
Treasury Stock Repurchased			—						—						—						—						(61)						(61)
Change in Treasury Stock - Stock Compensation Plans, Net			—						(27)						—						—						(20)						(47)
Balance at September 30, 2023			$	206					$	6,133					$	(7)					$	22,047					$	(621)					$	27,758

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

-5-

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EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Millions, Except Per Share Data)

(Unaudited)

			Common Stock						Additional Paid In Capital						Accumulated Other Comprehensive Loss						Retained Earnings						Common Stock Held In Treasury						Total Stockholders' Equity
Balance at December 31, 2023			$	206					$	6,166					$	(9)					$	22,634					$	(907)					$	28,090
Net Income			—						—						—						5,152						—						5,152
Common Stock Dividends Declared, $2.73 Per Share			—						—						—						(1,555)						—						(1,555)
Other Comprehensive Income			—						—						—						—						—						—
Restricted Stock and Restricted Stock Units, Net			—						(224)						—						—						224						—
Stock-Based Compensation Expenses			—						148						—						—						—						148
Treasury Stock Repurchased			—						—						—						—						(2,218)						(2,218)
Change in Treasury Stock - Stock Compensation Plans, Net			—						(32)						—						—						(11)						(43)
Balance at September 30, 2024			$	206					$	6,058					$	(9)					$	26,231					$	(2,912)					$	29,574

			Common Stock						Additional Paid In Capital						Accumulated Other Comprehensive Loss						Retained Earnings						Common Stock Held In Treasury						Total Stockholders' Equity
Balance at December 31, 2022			$	206					$	6,187					$	(8)					$	18,472					$	(78)					$	24,779
Net Income			—						—						—						5,606						—						5,606
Common Stock Dividends Declared, $3.475 Per Share			—						—						—						(2,031)						—						(2,031)
Other Comprehensive Income			—						—						1						—						—						1
Restricted Stock and Restricted Stock Units, Net			—						(156)						—						—						156						—
Stock-Based Compensation Expenses			—						126						—						—						—						126
Treasury Stock Repurchased			—						—						—						—						(676)						(676)
Change in Treasury Stock - Stock Compensation Plans, Net			—						(24)						—						—						(23)						(47)
Balance at September 30, 2023			$	206					$	6,133					$	(7)					$	22,047					$	(621)					$	27,758

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

-6-

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EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Millions)

(Unaudited)

			Nine Months Ended September 30,
			2024						2023
Cash Flows from Operating Activities
Reconciliation of Net Income to Net Cash Provided by Operating Activities:
Net Income			$	5,152					$	5,606
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization			3,089						2,562
Impairments			115						123
Stock-Based Compensation Expenses			148						126
Deferred Income Taxes			547						484
Gains on Asset Dispositions, Net			(39)						(95)
Other, Net			14						5
Dry Hole Costs			6						1
Mark-to-Market Financial Commodity and Other Derivative Contracts
Gains, Net			(269)						(520)
Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts			195						(130)
Other, Net			—						(2)
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable			200						(239)
Inventories			222						(331)
Accounts Payable			(188)						(70)
Accrued Taxes Payable			390						200
Other Assets			78						3
Other Liabilities			17						200
Changes in Components of Working Capital Associated with Investing Activities			(297)						313
Net Cash Provided by Operating Activities			9,380						8,236
Investing Cash Flows
Additions to Oil and Gas Properties			(4,105)						(4,025)
Additions to Other Property, Plant and Equipment			(902)						(638)
Proceeds from Sales of Assets			19						135
Changes in Components of Working Capital Associated with Investing Activities			297						(313)
Net Cash Used in Investing Activities			(4,691)						(4,841)
Financing Cash Flows
Long-Term Debt Repayments			—						(1,250)
Dividends Paid			(1,578)						(2,041)
Treasury Stock Purchased			(2,253)						(728)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan			11						10
Debt Issuance Costs			—						(8)
Repayment of Finance Lease Liabilities			(25)						(24)
Net Cash Used in Financing Activities			(3,845)						(4,041)
Effect of Exchange Rate Changes on Cash			—						—
Increase (Decrease) in Cash and Cash Equivalents			844						(646)
Cash and Cash Equivalents at Beginning of Period			5,278						5,972
Cash and Cash Equivalents at End of Period			$	6,122					$	5,326

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

-7-

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.    Summary of Significant Accounting Policies

General. The condensed consolidated financial statements of EOG Resources, Inc., together with its subsidiaries (collectively, EOG), included herein have been prepared by management without audit pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Accordingly, they reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the financial results for the interim periods presented. Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) have been condensed or omitted pursuant to such rules and regulations. However, management believes that the disclosures included either on the face of the financial statements or in these notes are sufficient to make the interim information presented not misleading. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in EOG's Annual Report on Form 10-K for the year ended December 31, 2023, filed on February 22, 2024 (EOG's 2023 Annual Report).

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three and nine months ended September 30, 2024, are not necessarily indicative of the results to be expected for the full year.

Change in Presentation. Effective January 1, 2024, EOG combined Transportation Costs and Gathering and Processing Costs into one line item titled Gathering, Processing and Transportation Costs within the Condensed Consolidated Statements of Income and Comprehensive Income. This presentation has been conformed for all periods presented and had no impact on previously reported Net Income.

Recently Issued Accounting Standards. In March 2024, the SEC adopted final rules under SEC Release No. 33-11275, The Enhancement and Standardization of Climate-Related Disclosures for Investors. The rules amending Regulation S-X will require public entities to provide certain climate-related information in their annual reports and registration statements. The rules will be effective for large accelerated filers commencing with the fiscal period beginning January 1, 2025. In April 2024, the SEC voluntarily issued an administrative stay of the implementation of the rules, pending judicial review. EOG is evaluating the impact of the final rules on its consolidated financial statements and disclosures.

2.    Stock-Based Compensation

As more fully discussed in Note 7 to the Consolidated Financial Statements included in EOG's 2023 Annual Report, EOG maintains various stock-based compensation plans. Stock-based compensation expense is included on the Condensed Consolidated Statements of Income and Comprehensive Income based upon the job function of the employees receiving the grants as follows (in millions):

			Three Months Ended September 30,												Nine Months Ended September 30,
			2024						2023						2024						2023
Lease and Well			$	22					$	16					$	50					$	39
Gathering, Processing and Transportation Costs			2						1						5						3
Exploration Costs			8						8						20						18
General and Administrative			26						32						73						66
Total			$	58					$	57					$	148					$	126

At September 30, 2024, approximately 13 million common shares remained available for grant under the EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (2021 Plan). EOG's policy is to issue shares related to the 2021 Plan grants from previously authorized unissued shares or treasury shares to the extent treasury shares are available.

-8-

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Stock Options and Stock-Settled Stock Appreciation Rights and Employee Stock Purchase Plan. The fair value of stock option grants and of stock-settled stock appreciation rights (SARs) grants is estimated using the Hull-White II binomial option pricing model. The fair value of Employee Stock Purchase Plan (ESPP) grants is estimated using the Black-Scholes-Merton model. Stock-based compensation expense related to stock option, SAR and ESPP grants totaled $8 million for both the three months ended September 30, 2024 and 2023, and $17 million and $20 million for the nine months ended September 30, 2024 and 2023, respectively.

EOG did not grant any stock options or SARs during the nine-month periods ended September 30, 2024 and 2023. Weighted average fair values and valuation assumptions used to value ESPP grants during the nine-month periods ended September 30, 2024 and 2023 are as follows:

									ESPP
									Nine Months Ended September 30,
									2024						2023
Weighted Average Fair Value of Grants									$	26.03					$	29.39
Expected Volatility									25.78		%				38.07		%
Risk-Free Interest Rate									5.17		%				5.02		%
Dividend Yield									2.87		%				2.67		%
Expected Life									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 ESPP grants.

The following table sets forth stock option and SAR transactions for the nine-month periods ended September 30, 2024 and 2023 (stock options and SARs in thousands):

			Nine Months Ended September 30, 2024												Nine Months Ended September 30, 2023
			Number of Stock Options/SARs						Weighted Average Exercise Price						Number of Stock Options/SARs						Weighted Average Exercise Price
Outstanding at January 1			2,843						$	79.22					4,225						$	77.49
Exercised (1)			(882)						75.46						(924)						76.88
Forfeited			(33)						86.69						(78)						86.69
Outstanding at September 30 (2)			1,928						$	80.81					3,223						$	77.45
Vested or Expected to Vest (3)			1,928						$	80.81					3,175						$	77.38
Exercisable at September 30 (4)			1,926						$	80.80					2,646						$	76.53

(1)The total intrinsic value of stock options/SARs exercised during the nine months ended September 30, 2024 and 2023 was $46 million in both periods. The intrinsic value is based upon the difference between the market price of EOG's common stock on the date of exercise and the exercise price of the stock options/SARs.

(2)The total intrinsic value of stock options/SARs outstanding at September 30, 2024 and 2023 was $83 million and $159 million, respectively. At September 30, 2024 and 2023, the weighted average remaining contractual life was 2.7 years and 3.6 years, respectively.

(3)The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2024 and 2023 was $83 million and $157 million, respectively. At September 30, 2024 and 2023, the weighted average remaining contractual life was 2.7 years and 3.6 years, respectively.

(4)The total intrinsic value of stock options/SARs exercisable at September 30, 2024 and 2023 was $83 million and $133 million, respectively. At September 30, 2024 and 2023, the weighted average remaining contractual life was 2.7 years and 3.3 years, respectively.

-9-

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

At September 30, 2024, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled $1 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 0.2 years.

Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Stock-based compensation expense related to restricted stock and restricted stock units totaled $39 million and $43 million for the three months ended September 30, 2024 and 2023, respectively, and $113 million and $95 million for the nine months ended September 30, 2024 and 2023, respectively.

The following table sets forth restricted stock and restricted stock unit transactions for the nine-month periods ended September 30, 2024 and 2023 (shares and units in thousands):

			Nine Months Ended September 30, 2024												Nine Months Ended September 30, 2023
			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			4,364						$	111.24					4,113						$	80.77
Granted			1,822						122.35						1,629						131.33
Released (1)			(1,264)						85.21						(1,208)						40.27
Forfeited			(143)						113.78						(85)						84.25
Outstanding at September 30 (2)			4,779						$	122.28					4,449						$	110.21

(1)The total intrinsic value of restricted stock and restricted stock units released during the nine months ended September 30, 2024 and 2023, was $155 million and $156 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the restricted stock and restricted stock units are released.

(2)The total intrinsic value of restricted stock and restricted stock units outstanding at September 30, 2024 and 2023, was $588 million and $564 million, respectively.

At September 30, 2024, unrecognized compensation expense related to restricted stock and restricted stock units totaled $396 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 2.0 years.

Performance Units. EOG grants restricted stock units with performance-based conditions (Performance Units) annually to its executive officers without cost to them. For the grants made prior to September 2022, as more fully discussed in the grant agreements, the applicable performance metric is EOG's total shareholder return (TSR) over a three-year performance period (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 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 the 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 Performance Period. At the end of the Performance Period, a performance multiple based on EOG's relative TSR ranking will be determined, with a minimum performance multiple of 0% and a maximum performance multiple of 200%. A specified modifier ranging from -70% to +70% will then be applied to the performance multiple based on EOG's average ROCE over the 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 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 average ROCE over the Performance Period.

The fair value of the Performance Units is estimated using a Monte Carlo simulation. Stock-based compensation expense related to the Performance Unit grants totaled $2 million and $6 million for the three months ended September 30, 2024 and 2023, respectively, and $9 million and $11 million for the nine months ended September 30, 2024 and 2023, respectively.

-10-

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The following table sets forth the Performance Unit transactions for the nine-month periods ended September 30, 2024 and 2023 (units in thousands):

			Nine Months Ended September 30, 2024												Nine Months Ended September 30, 2023
			Number of Units						Weighted Average Grant Date Fair Value						Number of Units						Weighted Average Grant Date Fair Value
Outstanding at January 1			630						$	95.49					688						$	83.82
Granted			109						130.31						109						141.59
Released (1)			(45)						43.33						(86)						79.98
Forfeited for Performance Multiple (2)			(135)						43.33						(86)						79.98
Outstanding at September 30 (3)			559			(4)			$	119.05					625						$	94.94

(1)The total intrinsic value of Performance Units released was $5 million and $10 million for the nine months ended September 30, 2024 and 2023, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Units are released.

(2)Upon completion of the Performance Period for the Performance Units granted in 2020 and 2019, a performance multiple of 25% and 50%, respectively, was applied to each of the grants resulting in a forfeiture of Performance Units in February 2024 and February 2023.

(3)The total intrinsic value of Performance Units outstanding at September 30, 2024 and 2023, was $69 million and $79 million, respectively.

(4)Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of zero and a maximum of 1,118 Performance Units could be outstanding.

At September 30, 2024, unrecognized compensation expense related to Performance Units totaled $24 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.6 years.

Other Stock Awards. In August 2024, and in recognition of EOG's 25th anniversary as an independent public company, EOG awarded 25 shares of EOG common stock to each of its non-executive officer employees. Stock-based compensation expense related to the awards totaled $9 million for both the three months and nine months ended September 30, 2024, and the intrinsic value of the awards was $9 million (based upon the closing price of EOG's common stock on the August 16, 2024 award date). A gross-up to account for income taxes was also recognized.

-11-

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

3.    Net Income Per Share

The following table sets forth the computation of Net Income Per Share for the three-month and nine-month periods ended September 30, 2024 and 2023 (in millions, except per share data):

			Three Months Ended September 30,												Nine Months Ended September 30,
			2024						2023						2024						2023
Numerator for Basic and Diluted Earnings Per Share -
Net Income			$	1,673					$	2,030					$	5,152					$	5,606
Denominator for Basic Earnings Per Share -
Weighted Average Shares			564						579						569						581
Potential Dilutive Common Shares -
Stock Options/SARs/ESPP			1						1						1						1
Restricted Stock/Units and Performance Units			3						3						3						2
Denominator for Diluted Earnings Per Share -
Adjusted Diluted Weighted Average Shares			568						583						573						584
Net Income Per Share
Basic			$	2.97					$	3.51					$	9.05					$	9.65
Diluted			$	2.95					$	3.48					$	8.99					$	9.60

The diluted earnings per share calculation excludes stock option, SAR and ESPP grants that were anti-dilutive. Shares underlying the excluded stock option, SAR and ESPP grants were zero for both the three-month periods ended September 30, 2024 and 2023, and zero and 1 million for the nine-month periods ended September 30, 2024 and 2023, respectively.

4.    Supplemental Cash Flow Information

Net cash paid for interest and income taxes was as follows for the nine-month periods ended September 30, 2024 and 2023 (in millions):

			Nine Months Ended September 30,
			2024						2023
Interest (1)			$	75					$	110
Income Taxes, Net of Refunds Received			$	587					$	876

(1)Net of capitalized interest of $32 million and $24 million for the nine months ended September 30, 2024 and 2023, respectively.

EOG's accrued capital expenditures and amounts recorded within accounts payable at September 30, 2024 and 2023 were $690 million and $716 million, respectively.

Non-cash investing activities for the nine months ended September 30, 2024 and 2023, included additions of $106 million and $154 million, respectively, to EOG's oil and gas properties as a result of property exchanges.

Operating activities for the nine months ended September 30, 2023, included net cash received of $324 million related to the change in collateral posted for financial commodity derivative contracts. EOG had no collateral posted or held during the nine months ended September 30, 2024. For related discussion, see Note 12. This amount is reflected in Other Liabilities within the Changes in Components of Working Capital and Other Assets and Liabilities line item on the Condensed Consolidated Statements of Cash Flows.

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

5.    Segment Information

Selected financial information by reportable segment is presented below for the three-month and nine-month periods ended September 30, 2024 and 2023 (in millions):

			Three Months Ended September 30,												Nine Months Ended September 30,
			2024						2023						2024						2023
Operating Revenues and Other
United States			$	5,881					$	6,164					$	17,897					$	17,625
Trinidad			84						48						216						203
Other International (1)			—						—						—						1
Total			$	5,965					$	6,212					$	18,113					$	17,829
Operating Income (Loss)
United States			$	2,063					$	2,559					$	6,474					$	7,032
Trinidad			30						17						62						99
Other International (1)			(4)						(19)						(46)						(32)
Total			2,089						2,557						6,490						7,099
Reconciling Items
Other Income, Net			76						52						204						168
Interest Expense, Net			(31)						(36)						(100)						(113)
Income Before Income Taxes			$	2,134					$	2,573					$	6,594					$	7,154

(1)    Other International primarily consists of EOG's international exploration programs and Canada operations. EOG is continuing the process of exiting its Canada operations. EOG began an exploration program in Australia in the third quarter of 2021.

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Total assets by reportable segment are presented below at September 30, 2024 and December 31, 2023 (in millions):

			At September 30, 2024						At December 31, 2023
Total Assets
United States			$	44,867					$	42,674
Trinidad			1,094						1,063
Other International (1)			190						120
Total			$	46,151					$	43,857

(1)    Other International primarily consists of EOG's international exploration programs and Canada operations. EOG is continuing the process of exiting its Canada operations. EOG began an exploration program in Australia in the third quarter of 2021.

6.    Asset Retirement Obligations

The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of short-term and long-term legal obligations associated with the retirement of property, plant and equipment for the nine-month periods ended September 30, 2024 and 2023 (in millions):

			Nine Months Ended September 30,
			2024						2023
Carrying Amount at January 1			$	1,506					$	1,328
Liabilities Incurred			39						49
Liabilities Settled (1)			(50)						(80)
Accretion			43						37
Revisions			(84)						166
Foreign Currency Translations			(1)						—
Carrying Amount at September 30			$	1,453					$	1,500
Current Portion			$	44					$	42
Noncurrent Portion			$	1,409					$	1,458

(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 Condensed Consolidated Balance Sheets.

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

7.    Exploratory Well Costs

EOG's net changes in capitalized exploratory well costs for the nine-month period ended September 30, 2024, are presented below (in millions):

			Nine Months Ended September 30, 2024
Balance at January 1			$	76
Additions Pending the Determination of Proved Reserves			46
Reclassifications to Proved Properties			(58)
Costs Charged to Expense (1)			(1)
Balance at September 30			$	63

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

At September 30, 2024, EOG had no exploratory wells capitalized for a period of greater than one year.

8.    Commitments and Contingencies

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

9.    Pension and Postretirement Benefits

Pension Plans. EOG has a defined contribution pension plan in place for most of its employees in the United States. EOG's contributions to the pension plan are based on various percentages of compensation and, in some instances, are based upon the amount of the employees' contributions. EOG's total costs recognized for the pension plan were $46 million and $42 million for the nine months ended September 30, 2024 and 2023, respectively. In addition, EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan, both of which are available to most of the employees of the Trinidadian subsidiary, the costs of which are not material.

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

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

10.    Long-Term Debt and Common Stock

Long-Term Debt. EOG had no outstanding commercial paper borrowings at September 30, 2024 and December 31, 2023, and did not utilize any commercial paper borrowings during the nine months ended September 30, 2024 and 2023.

At September 30, 2024, the $500 million aggregate principal amount of EOG's 3.15% Senior Notes due 2025 was classified as long-term debt based upon EOG's intent and ability to ultimately replace such amount with other long-term debt.

EOG currently has a $1.9 billion senior unsecured Revolving Credit Agreement (Agreement) with domestic and foreign lenders (Banks). The Agreement has a scheduled maturity date of June 7, 2028, 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 $1.9 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 Secured Overnight Financing Rate (SOFR) plus 0.1% plus an applicable margin or the base rate (as defined in the Agreement) plus an applicable margin. The applicable margin used in connection with interest rates and fees will be based on EOG's credit rating for its senior unsecured long-term debt at the applicable time. 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 September 30, 2024, EOG was in compliance with this financial covenant. At September 30, 2024, and December 31, 2023, there were no borrowings or letters of credit outstanding under the Agreement. The SOFR and base rate (inclusive of the applicable margins), had there been any amounts borrowed under the Agreement at September 30, 2024, would have been 5.85% and 8.00%, respectively.

Common Stock. In November 2021, the Board of Directors (Board) established a new share repurchase authorization that allows for the repurchase by EOG of up to $5 billion of its common stock (Share Repurchase Authorization). During the nine months ended September 30, 2024, EOG repurchased 18.0 million shares of common stock for approximately $2,198 million (inclusive of transaction fees and commissions) pursuant to the Share Repurchase Authorization. As of September 30, 2024, approximately $1.8 billion remained available for repurchases under the Share Repurchase Authorization. Included in the Treasury Stock Repurchased amounts on the Condensed Consolidated Statements of Stockholders' Equity for the nine months ended September 30, 2024, is $20 million of estimated federal excise taxes. Subsequent to September 30, 2024, the Board increased the Share Repurchase Authorization from $5 billion to $10 billion, effective November 7, 2024.

Under the Share Repurchase Authorization, EOG may repurchase shares from time to time, at management's discretion, in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. The timing and amount of repurchases is at the discretion of EOG's management and depends on a variety of factors, including the trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares are held as treasury shares and are available for general corporate purposes. The Share Repurchase Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board at any time.

On February 22, 2024, the Board declared a quarterly cash dividend on the common stock of $0.91 per share paid on April 30, 2024, to stockholders of record as of April 16, 2024.

On May 2, 2024, the Board declared a quarterly cash dividend on the common stock of $0.91 per share paid on July 31, 2024, to stockholders of record as of July 17, 2024.

On August 1, 2024, the Board declared a quarterly cash dividend on the common stock of $0.91 per share paid on October 31, 2024, to stockholders of record as of October 17, 2024.

On November 7, 2024, the Board increased the quarterly cash dividend on the common stock from the previous $0.91 per share to $0.975 per share, effective beginning with the dividend payable on January 31, 2025, to stockholders of record as of January 17, 2025.

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

11.    Fair Value Measurements

Recurring Fair Value Measurements. As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's 2023 Annual Report, certain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Condensed Consolidated Balance Sheets. The following table provides fair value measurement information within the fair value hierarchy for certain of EOG's financial assets and liabilities carried at fair value on a recurring basis at September 30, 2024 and December 31, 2023 (in millions):

			Fair Value Measurements Using:
			Quoted Prices in Active Markets (Level 1)						Significant Other Observable Inputs (Level 2)						Significant Unobservable Inputs (Level 3)						Total
At September 30, 2024
Financial Assets:
Natural Gas Basis Swaps			$	—					$	2					$	—					$	2
Brent Crude Oil (Brent) Linked Gas Sales Contract			—						—						148						148
Financial Liabilities:
Natural Gas Swaps			—						73						—						73
At December 31, 2023
Financial Assets:
Natural Gas Swaps			$	—					$	105					$	—					$	105
Natural Gas Basis Swaps			—						2						—						2
Financial Liabilities:
Natural Gas Swaps			—						104						—						104

See Note 12 for the balance sheet amounts and classification of EOG's financial commodity and other derivative instruments at September 30, 2024 and December 31, 2023.

The estimated fair value of financial commodity and other derivative contracts was based upon forward commodity price curves based on quoted market prices. For the Brent Linked Gas Sales Contract, the estimated fair value was based on EOG's estimates of (and assumptions regarding) significant Level 3 inputs, including future crude oil and natural gas prices. These Level 3 inputs are immaterial to the financial statements. Financial commodity and other derivative contracts were valued utilizing an independent third-party derivative valuation provider who uses various types of valuation models, as applicable.

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

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 estimates of (and assumptions regarding) significant Level 3 inputs, including future crude oil, natural gas liquids (NGLs) and natural gas prices, operating costs, development expenditures, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated using the Income Approach described in the Financial Accounting Standards Board's Fair Value Measurement Topic of the Accounting Standards Codification (ASC). In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.

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

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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

At both September 30, 2024 and December 31, 2023, EOG had outstanding $3,640 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately $3,593 million and $3,574 million, respectively. The estimated fair value of debt was based upon quoted market prices and, where such prices were not available, other observable (Level 2) inputs regarding interest rates available to EOG at the end of each respective period.

Natural Gas Sales Linked to Brent Crude Oil. In February 2024, EOG entered into a 10-year agreement, commencing in 2027, to sell 180,000 million British Thermal Units per day (MMBtud) of its domestic natural gas production, with 140,000 MMBtud to be sold at a price indexed to Brent and the remaining volumes to be sold at a price indexed to Brent or a U.S. Gulf Coast gas index. It was determined that this agreement meets the definition of a derivative under the Derivatives and Hedging Topic of the ASC and does not qualify for the normal purchases and normal sales scope exception. As such, this agreement is accounted for as a derivative using the mark-to-market accounting method. Changes in the fair value are recognized as gains or losses in the period of change on the Condensed Consolidated Statements of Income and Comprehensive Income.

12.    Risk Management Activities

Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2023 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity and other derivative contracts as accounting hedges and, accordingly, accounts for financial commodity and other derivative contracts using the mark-to-market accounting method.

Financial Commodity Derivative Contracts. Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the nine-month period ended September 30, 2024 (closed) and outstanding as of September 30, 2024. Natural gas volumes are presented in MMBtud and prices are presented in dollars per million British Thermal Units ($/MMBtu).

Natural Gas Financial Price Swap Contracts

Contracts Sold

Period

Settlement Index

Volume (MMBtud in thousands)

Weighted Average Price ($/MMBtu)

January - October 2024 (closed)

New York Mercantile Exchange (NYMEX) Henry Hub

725

$

3.07

November - December 2024

NYMEX Henry Hub

725

3.07

January - December 2025

NYMEX Henry Hub

725

3.07

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Natural Gas Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume (MMBtud in thousands)

Weighted Average Price Differential ($/MMBtu)

January - September 2024 (closed)

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

10

$

0.00

October - 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 and Other Derivative Instruments Location on Balance Sheet. The following table sets forth the amounts and classification of EOG's outstanding financial commodity and other derivative instruments at September 30, 2024 and December 31, 2023. Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions):

												Fair Value at
Description						Location on Balance Sheet						September 30, 2024						December 31, 2023
Asset Derivatives
Crude oil, NGLs and natural gas financial derivative contracts -
Current portion						Assets from Price Risk Management Activities (1)						$	—					$	106
Brent Linked Gas Sales Contract -
Noncurrent Portion						Other Assets (2)						148						—
Liability Derivatives
Crude oil, NGLs and natural gas financial derivative contracts -
Current Portion						Liabilities from Price Risk Management Activities (3)						$	32					$	—
Noncurrent portion						Other Liabilities (4)						39						103

(1)    The current portion of Assets from Price Risk Management Activities consists of gross assets of $106 million at December 31, 2023.

(2)    The noncurrent portion related to the Brent Linked Gas Sales Contract consists of gross assets of $148 million at September 30, 2024.

(3)    The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $33 million, partially offset by gross assets of $1 million at September 30, 2024.

(4)    The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $39 million at September 30, 2024. The noncurrent portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $104 million, partially offset by gross assets of $1 million at December 31, 2023.

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

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EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)

(Unaudited)

All of EOG's financial commodity derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that require EOG, if it is the party in a net liability position, to post collateral when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings. In addition, the ISDAs may also provide that, as a result of certain circumstances, including certain events that cause EOG's credit ratings to become materially weaker than its then-current ratings, the counterparty may require all outstanding derivatives under the ISDAs to be settled immediately. See Note 11 for the aggregate fair value of all derivative instruments that were in a net liability position at September 30, 2024 and December 31, 2023. EOG had no collateral posted and no collateral held at September 30, 2024 and December 31, 2023. EOG had no collateral posted and no collateral held at November 6, 2024.

13.  Acquisitions and Divestitures

During the nine months ended September 30, 2024, EOG paid cash of $139 million, primarily to acquire a gathering system in South Texas. Additionally, during the nine months ended September 30, 2024, EOG recognized net gains on asset dispositions of $39 million and received proceeds of $19 million, primarily due to lease exchanges and dispositions in the Delaware Basin and the Eagle Ford as well as the sale of certain other assets.

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

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PART I.  FINANCIAL INFORMATION

ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EOG RESOURCES, INC.

Overview

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

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

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

For the first nine months of 2024, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were $77.55 per barrel and $2.10 per million British thermal units (MMBtu), respectively, representing an increase of 0.2% and a decrease of 22%, respectively, from the average NYMEX prices for the same period in 2023. Market prices for NGLs are influenced by the components extracted, including ethane, propane and butane and natural gasoline, among others, and the respective market pricing for each component.

Based on EOG's tax position, EOG's price sensitivity as of September 30, 2024, for each $1.00 per barrel increase or decrease in wellhead crude oil and condensate price, combined with the estimated change in NGL price, is approximately $153 million for net income and $196 million for pretax cash flows from operating activities, in each case for the full-year 2024.

Including the impact of EOG's natural gas financial derivative contracts and based on EOG's tax position and the portion of EOG's anticipated natural gas volumes for which prices have not (as of September 30, 2024) been determined under long-term marketing contracts, EOG's price sensitivity as of September 30, 2024, for each $0.10 per thousand cubic feet increase or decrease in wellhead natural gas price, is approximately $27 million for net income and $34 million for pretax cash flows from operating activities, in each case for the full-year 2024.

Inflation Considerations. As further discussed in EOG's Annual Report on Form 10-K for the year ended December 31, 2023, filed on February 22, 2024 (EOG's 2023 Annual Report), EOG has, beginning in the second quarter of 2023, seen the inflationary pressures on its operating costs and capital expenditures (i.e., costs of fuel, steel, labor and drilling and completion services) diminish and, in certain circumstances, EOG has seen a decline in prices.

Despite such declining prices, EOG plans to continue its focus on increasing its drilling, completion and operating efficiencies and improving the performance of its wells. Such focus and the related initiatives EOG has undertaken, together with the flexibility provided by its multi-basin drilling portfolio, allowed EOG to largely offset the inflationary pressures it experienced beginning in the second half of 2021 and through the first three months of 2023.

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However, there can be no assurance that such efforts will offset, largely or at all, the impacts of any future inflationary pressures on EOG's operating costs and capital expenditures. Further, EOG expects the market for drilling and completion services and related labor and materials will continue to fluctuate and, as a result, there can be no assurance regarding the timing and impact of any future price changes on EOG's operating costs and capital expenditures and, in turn, on EOG's cash flows, results of operations, liquidity, capital resources, cash requirements or financial position or its ability to conduct its day-to-day drilling, completion and production operations.

Climate Change. For discussion of climate change matters and related regulatory matters, including potential developments related to climate change and the potential impacts and risks of such developments on EOG, see ITEM 1A, Risk Factors and the related discussion in ITEM 1, Business - Regulation of EOG's 2023 Annual Report. EOG will continue to monitor and assess any climate change-related developments, including the SEC's climate-related disclosure rules adopted in March 2024, that could impact EOG and the oil and gas industry, to determine the impact on its business and operations, and take appropriate actions where necessary.

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

During the first nine months of 2024, EOG continued to (i) focus on improving well performance and operating efficiencies, (ii) evaluate certain potential crude oil and condensate, NGLs and natural gas exploration and development prospects and (iii) look for opportunities to add drilling inventory through leasehold acquisitions, farm-ins, exchanges or tactical or bolt-on acquisitions. On a volumetric basis, as calculated using a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas, crude oil and condensate and NGLs production accounted for approximately 72% and 73% of EOG's United States production during the first nine months of 2024 and 2023, respectively. During the first nine months of 2024, EOG's drilling and completion activities occurred primarily in the Delaware Basin play and the Eagle Ford play. EOG's major producing areas in the United States are in New Mexico and Texas.

Trinidad. In Trinidad, EOG continues to deliver natural gas under existing supply contracts. Several fields in the South East Coast Consortium (SECC) Block, Modified U(a) Block, Block 4(a), the Banyan Field and the Sercan Area have been developed and are producing natural gas which is sold to the National Gas Company of Trinidad and Tobago Limited, and crude oil and condensate which is sold to Heritage Petroleum Company Limited.

During the first nine months of 2024, EOG completed one net developmental well and one net exploratory well from the recently installed Osprey B platform in the Modified U(a) Block. EOG also completed one net exploratory well and is currently completing another exploratory well from the Oilbird platform in the SECC Block. In June 2024, EOG relinquished its rights to a portion of the contract area governed by the Trinidad Northern Area License located offshore the southwest coast of Trinidad. In July 2024, EOG signed a farmout agreement with BP Trinidad and Tobago LLC, which allows EOG to earn a 50% working interest to develop the Coconut gas field in the East Mayaro and South East Galeota Areas. Additionally, EOG is currently in discussions with the Government of Trinidad and Tobago regarding the potential award of the Lower Reverse L and NCMA 4(a) Blocks in respect of the 2023 shallow water bid round. In the fourth quarter of 2024, EOG expects to recomplete two wells in the Sercan Area and also drill an exploratory well in the deep Teak, Samaan and Poui Area. Additionally, EOG expects to complete construction and installation of the platform and commence pipeline installation in the Mento Area.

Other International. In November 2021, a subsidiary of EOG was granted an exploration permit for the WA-488-P Block, located offshore Western Australia. During the first nine months of 2024, EOG continued to prepare for the drilling of an exploration well in this block.

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

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2024 Capital and Operating Plan. Total 2024 capital expenditures are estimated to range from approximately $6.1 billion to $6.3 billion, including exploration and development drilling, facilities, leasehold acquisitions, capitalized interest, dry hole costs and other property, plant and equipment and excluding property acquisitions, asset retirement costs, non-cash exchanges and transactions and exploration costs incurred as operating expenses. EOG plans to continue to focus a substantial portion of its exploration and development expenditures in its major producing areas in the United States. In particular, EOG will be focused on United States drilling activity in its plays where it generates the highest rates of return - specifically, in the Delaware Basin, Eagle Ford, Utica and Rocky Mountain area. To further enhance the economics of these plays, EOG expects to continue to improve well performance and to focus on improving operating efficiencies; see the above related discussion. Full-year 2024 total crude oil, NGLs and natural gas production is expected to increase modestly versus 2023. In addition, EOG plans to continue to spend a portion of its anticipated 2024 capital expenditures on leasing acreage, evaluating new prospects, transportation infrastructure and environmental projects.

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

Capital Structure. One of management's key strategies is to maintain a strong balance sheet with a consistently below average debt-to-total capitalization ratio as compared to those in EOG's peer group. EOG's debt-to-total capitalization ratio was 11% at September 30, 2024 and 12% at December 31, 2023. As used in this calculation, total capitalization represents the sum of total current and long-term debt and total stockholders' equity.

At September 30, 2024, EOG maintained a strong financial and liquidity position, including $6.1 billion of cash and cash equivalents on hand and $1.9 billion of availability under its senior unsecured revolving credit facility. At September 30, 2024, the $500 million aggregate principal amount of its 3.15% Senior Notes due 2025 was classified as long-term debt based upon EOG's intent and ability to ultimately replace such amount with other long-term debt.

The Internal Revenue Service previously announced tax relief related to 2024 severe weather events occurring in various Texas counties, including Harris County where EOG's corporate offices are located. The tax relief permits eligible taxpayers to postpone certain tax filings and payments.

EOG has significant flexibility with respect to financing alternatives, including borrowings under its commercial paper program, bank borrowings, borrowings under its senior unsecured revolving credit facility, joint development agreements and similar agreements and equity and debt offerings. For related discussion, see ITEM 7, Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity included in EOG's 2023 Annual Report.

Cash Return Framework. In November 2023, EOG announced an increase in its cash return commitment - specifically, a commitment, effective beginning with fiscal year 2024, to return a minimum of 70% of annual net cash provided by operating activities before certain balance sheet-related changes, less total capital expenditures, to stockholders, through a combination of quarterly dividends, special dividends and share repurchases.

For discussion regarding EOG's payment of dividends and share repurchases, see ITEM 1A, Risk Factors and ITEM 5, Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities in EOG's 2023 Annual Report and Part II, Item 2, Unregistered Sales of Equity Securities and Use of Proceeds in this Quarterly Report on Form 10-Q.

Dividend Declarations. On February 22, 2024, the Board of Directors (Board) declared a quarterly cash dividend on the common stock of $0.91 per share paid on April 30, 2024, to stockholders of record as of April 16, 2024.

On May 2, 2024, the Board declared a quarterly cash dividend on the common stock of $0.91 per share paid on July 31, 2024, to stockholders of record as of July 17, 2024.

On August 1, 2024, the Board declared a quarterly cash dividend on the common stock of $0.91 per share paid on October 31, 2024, to stockholders of record as of October 17, 2024.

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On November 7, 2024, the Board increased the quarterly cash dividend on the common stock from the previous $0.91 per share to $0.975 per share, effective beginning with the dividend payable on January 31, 2025, to stockholders of record as of January 17, 2025.

Share Repurchases. In November 2021, the Board established a new share repurchase authorization that allows for the repurchase by EOG of up to $5 billion of its common stock (Share Repurchase Authorization). During the three and nine months ended September 30, 2024, EOG repurchased 6.1 million and 18.0 million shares of common stock for approximately $758 million and $2,198 million (inclusive of transaction fees and commissions), respectively, pursuant to the Share Repurchase Authorization. As of September 30, 2024, approximately $1.8 billion remained available for repurchases under the Share Repurchase Authorization. Included in the Treasury Stock Repurchased amounts on the Condensed Consolidated Statements of Stockholders' Equity for the three and nine months ended September 30, 2024, are $7 million and $20 million, respectively, of estimated federal excise taxes. Subsequent to September 30, 2024, the Board increased the Share Repurchase Authorization from $5 billion to $10 billion, effective November 7, 2024.

Under the Share Repurchase Authorization, EOG may repurchase shares from time to time, at management's discretion, in accordance with applicable securities laws, including through open market transactions, privately negotiated transactions or any combination thereof. The timing and amount of repurchases is at the discretion of EOG's management and depends on a variety of factors, including the trading price of EOG's common stock, corporate and regulatory requirements, and other market and economic conditions. Repurchased shares are held as treasury shares and are available for general corporate purposes. The Share Repurchase Authorization has no time limit, does not require EOG to repurchase a specific number of shares and may be modified, suspended, or terminated by the Board at any time.

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Results of Operations

The following review of operations for the three months and nine months ended September 30, 2024 and 2023 should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form 10‑Q.

Three Months Ended September 30, 2024 vs. Three Months Ended September 30, 2023

Operating Revenues. During the third quarter of 2024, operating revenues decreased $247 million, or 4%, to $5,965 million from $6,212 million for the same period of 2023. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the third quarter of 2024 decreased $251 million, or 5%, to $4,384 million from $4,635 million for the same period of 2023. EOG recognized net gains on the mark-to-market of financial commodity and other derivative contracts of $79 million for the third quarter of 2024 compared to net gains of $43 million for the same period of 2023. Gathering, processing and marketing revenues for the third quarter of 2024 increased $3 million to $1,481 million from $1,478 million for the same period of 2023. Net losses on asset dispositions were $7 million for the third quarter of 2024 compared to net gains of $35 million for the same period of 2023.

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Wellhead volume and price statistics for the three-month periods ended September 30, 2024 and 2023 were as follows:

			Three Months Ended September 30,
			2024									2023
Crude Oil and Condensate Volumes (MBbld) (1)
United States			491.8									482.8
Trinidad			1.2									0.5
Total			493.0									483.3
Average Crude Oil and Condensate Prices ($/Bbl) (2)
United States			$	76.95								$	83.61
Trinidad			63.15									71.38
Composite			76.92									83.60
Natural Gas Liquids Volumes (MBbld) (1)
United States			254.3									231.1
Total			254.3									231.1
Average Natural Gas Liquids Prices ($/Bbl) (2)
United States			$	22.42								$	23.56
Natural Gas Volumes (MMcfd) (1)
United States			1,745									1,562
Trinidad			225									142
Total			1,970									1,704
Average Natural Gas Prices ($/Mcf) (2)
United States			$	1.84								$	2.59
Trinidad			3.68									3.41
Composite			2.05									2.66
Crude Oil Equivalent Volumes (MBoed) (3)
United States			1,037.1									974.2
Trinidad			38.6									24.3
Total			1,075.7									998.5
Total MMBoe (3)			99.0									91.9

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

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

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

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Wellhead crude oil and condensate revenues for the third quarter of 2024 decreased $229 million, or 6%, to $3,488 million from $3,717 million for the same period of 2023. The decrease was due to a lower composite average price ($317 million), partially offset by an increase of 9.7 MBbld, or 2%, in wellhead crude oil and condensate production ($88 million). Increased production was primarily from the Utica. EOG's composite wellhead crude oil and condensate price for the third quarter of 2024 decreased 8% to $76.92 per barrel compared to $83.60 per barrel for the same period of 2023.

NGL revenues for the third quarter of 2024 increased $23 million, or 5%, to $524 million from $501 million for the same period of 2023 due to an increase of 23.2 MBbld, or 10%, in NGL deliveries ($51 million), partially offset by a lower composite average price ($28 million). Increased production was primarily from the Permian Basin. EOG's composite NGL price for the third quarter of 2024 decreased 5% to $22.42 per barrel compared to $23.56 per barrel for the same period of 2023.

Wellhead natural gas revenues for the third quarter of 2024 decreased $45 million, or 11%, to $372 million from $417 million for the same period of 2023. The decrease was due to a lower composite average price ($114 million), partially offset by an increase in natural gas deliveries ($69 million). Natural gas deliveries for the third quarter of 2024 increased 266 MMcfd, or 16%, compared to the same period of 2023 due primarily to increased production of associated natural gas from the Permian Basin and higher natural gas deliveries in Trinidad. EOG's composite wellhead natural gas price for the third quarter of 2024 decreased 23% to $2.05 per Mcf compared to $2.66 per Mcf for the same period of 2023.

During the third quarter of 2024, EOG recognized net gains on the mark-to-market of financial commodity and other derivative contracts of $79 million compared to net gains of $43 million for the same period of 2023. The net gains of $79 million included gains of $15 million related to the Brent crude oil (Brent) linked gas sales contract. During the third quarter of 2024, net cash received from settlements of financial commodity derivative contracts was $61 million compared to net cash received from settlements of financial commodity derivative contracts of $23 million for the same period of 2023.

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

Gathering, processing and marketing revenues less marketing costs for the third quarter of 2024 decreased $114 million as compared to the same period of 2023 primarily due to lower margins on crude oil marketing activities.

Operating and Other Expenses.  For the third quarter of 2024, operating expenses of $3,876 million were $221 million higher than the $3,655 million incurred during the third quarter of 2023.  The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended September 30, 2024 and 2023:

			Three Months Ended September 30,
			2024						2023
Lease and Well			$	3.96					$	4.02
Gathering, Processing and Transportation Costs (GP&T)			4.50						4.42
Depreciation, Depletion and Amortization (DD&A) -
Oil and Gas Properties			9.89						9.31
Other Property, Plant and Equipment			0.53						0.47
General and Administrative (G&A)			1.69						1.75
Interest Expense, Net			0.31						0.39
Total (1)			$	20.88					$	20.36

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

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The primary factors impacting the cost components of per-unit rates of lease and well, GP&T, DD&A, G&A and interest expense, net for the three months ended September 30, 2024, compared to the same period of 2023, are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

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

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

Lease and well expenses of $392 million for the third quarter of 2024 increased $23 million from $369 million for the same prior year period primarily due to increased operating and maintenance costs ($18 million) and increased lease and well administrative expenses ($6 million), both in the United States. Lease and well expenses increased in the United States primarily due to increased operating activities resulting from increased production.

GP&T costs represent costs to process and deliver hydrocarbon products from the lease to a downstream point of sale. GP&T costs include operating and maintenance expenses from EOG-owned assets, fees paid to third party operators and administrative expenses associated with operating EOG's GP&T assets. EOG pays third parties to process the majority of its natural gas production to extract NGLs.

GP&T costs of $445 million for the third quarter of 2024 increased $39 million from $406 million for the same prior year period primarily due to increased GP&T costs related to increased production in the Permian Basin and Utica.

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

DD&A expenses for the third quarter of 2024 increased $133 million to $1,031 million from $898 million for the same prior year period. DD&A expenses associated with oil and gas properties for the third quarter of 2024 were $123 million higher than the same prior year period. The increase primarily reflects increased production in the United States ($54 million) and in Trinidad ($8 million), and increased unit rates in the United States ($50 million) and in Trinidad ($11 million). DD&A expenses associated with other property, plant and equipment for the third quarter of 2024 were $10 million higher than the same prior year period primarily due to an increase in expenses related to GP&T assets and equipment.

G&A expenses of $167 million for the third quarter of 2024 increased $6 million from $161 million for the same prior year period primarily due to increased professional and other services costs.

Interest expense, net of $31 million for the third quarter of 2024 decreased $5 million compared to the same prior year period primarily due to higher capitalized interest.

Impairments include: amortization of unproved oil and gas property costs as well as impairments of proved oil and gas properties; other property, plant and equipment; and other assets. Unproved properties with acquisition costs that are not individually significant are aggregated, and the portion of such costs estimated to be nonproductive is amortized over the remaining lease term. Unproved properties with individually significant acquisition costs are reviewed individually for impairment.

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The following table sets forth impairments for the third quarter of 2024 and 2023 (in millions):

			Three Months Ended September 30,
			2024						2023
Proved properties			$	1					$	23
Unproved properties			14						30
Other assets			—						—
Firm commitment contracts			—						1
Total			$	15					$	54

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

Taxes other than income for the third quarter of 2024 decreased $58 million to $283 million (6.5% of wellhead revenues) from $341 million (7.4% of wellhead revenues) for the same prior year period. The decrease in taxes other than income was primarily due to increased state severance tax refunds ($30 million) and decreased severance/production taxes ($25 million), all in the United States.

Other income, net of $76 million for the third quarter of 2024 increased $24 million from $52 million for the same prior year period. The increase was primarily due to increased interest income.

Income taxes of $461 million for the third quarter of 2024 decreased from income taxes of $543 million for the third quarter of 2023 primarily due to decreased pretax income.  The net effective tax rate for the third quarter of 2024 increased to 22% from 21% for the third quarter of 2023.

Nine Months Ended September 30, 2024 vs. Nine Months Ended September 30, 2023

Operating Revenues. During the first nine months of 2024, operating revenues increased $284 million, or 2%, to $18,113 million from $17,829 million for the same period of 2023. Total wellhead revenues for the first nine months of 2024 increased $450 million, or 4%, to $13,269 million from $12,819 million for the same period of 2023. During the first nine months of 2024, EOG recognized net gains on the mark-to-market of financial commodity and other derivative contracts of $269 million compared to net gains of $520 million for the same period of 2023. Gathering, processing and marketing revenues for the first nine months of 2024 increased $126 million, or 3%, to $4,459 million from $4,333 million for the same period of 2023. Net gains on asset dispositions were $39 million for the first nine months of 2024 compared to net gains of $95 million for the same period of 2023.

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Wellhead volume and price statistics for the nine-month periods ended September 30, 2024 and 2023 were as follows:

			Nine Months Ended September 30,
			2024									2023
Crude Oil and Condensate Volumes (MBbld)
United States			489.6									472.0
Trinidad			0.8									0.6
Total			490.4									472.6
Average Crude Oil and Condensate Prices ($/Bbl) (1)
United States			$	79.36								$	78.69
Trinidad			66.22									68.37
Composite			79.34									78.67
Natural Gas Liquids Volumes (MBbld)
United States			243.7									219.7
Total			243.7									219.7
Average Natural Gas Liquids Prices ($/Bbl) (1)
United States			$	23.25								$	23.35
Natural Gas Volumes (MMcfd)
United States			1,691									1,517
Trinidad			209									154
Total			1,900									1,671
Average Natural Gas Prices ($/Mcf) (1)
United States			$	1.84								$	2.70
Trinidad			3.57									3.59
Composite			2.03									2.78
Crude Oil Equivalent Volumes (MBoed)
United States			1,015.0									944.6
Trinidad			35.8									26.2
Total			1,050.8									970.8
Total MMBoe			287.9									265.0

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

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Wellhead crude oil and condensate revenues for the first nine months of 2024 increased $509 million, or 5%, to $10,660 million from $10,151 million for the same period of 2023 due to an increase of 17.8 MBbld, or 4%, in wellhead crude oil and condensate production ($420 million) and a higher composite average price ($89 million). Increased production was primarily in the Permian Basin and Utica. EOG's composite wellhead crude oil and condensate price for the first nine months of 2024 increased 1% to $79.34 per barrel compared to $78.67 per barrel for the same period of 2023.

NGL revenues for the first nine months of 2024 increased $152 million, or 11%, to $1,552 million from $1,400 million for the same period of 2023 due to an increase of 24.0 MBbld, or 11%, in NGL deliveries ($159 million), partially offset by a lower composite average price ($7 million). Increased production was primarily from the Permian Basin. EOG's composite NGL price for the first nine months of 2024 decreased to $23.25 per barrel compared to $23.35 per barrel for the same period of 2023.

Wellhead natural gas revenues for the first nine months of 2024 decreased $211 million, or 17%, to $1,057 million from $1,268 million for the same period of 2023. The decrease was due to a lower composite average price ($393 million), partially offset by an increase in natural gas deliveries ($182 million). Natural gas deliveries for the first nine months of 2024 increased 229 MMcfd, or 14%, compared to the same period of 2023 due primarily to increased production of associated natural gas from the Permian Basin and higher natural gas deliveries in Trinidad. EOG's composite wellhead natural gas price for the first nine months of 2024 decreased 27% to $2.03 per Mcf compared to $2.78 per Mcf for the same period of 2023.

During the first nine months of 2024, EOG recognized net gains on the mark-to-market of financial commodity and other derivative contracts of $269 million compared to net gains of $520 million for the same period of 2023. The net gains of $269 million included gains of $148 million related to the Brent linked gas sales contract. During the first nine months of 2024, net cash received from settlements of financial commodity derivative contracts was $195 million. Net cash paid for settlements of financial commodity derivative contracts was $130 million for the same period of 2023.

Gathering, processing and marketing revenues less marketing costs for the first nine months of 2024 decreased $68 million as compared to the same period of 2023 primarily due to lower margins on crude oil marketing activities, sand sales and natural gas marketing activities.

Operating and Other Expenses. For the first nine months of 2024, operating expenses of $11,623 million were $893 million higher than the $10,730 million incurred during the same period of 2023. The following table presents the costs per Boe for the nine-month periods ended September 30, 2024 and 2023:

			Nine Months Ended September 30,
			2024						2023
Lease and Well			$	4.09					$	4.06
GP&T			4.45						4.52
DD&A -
Oil and Gas Properties			10.20						9.19
Other Property, Plant and Equipment			0.53						0.48
G&A			1.67						1.69
Interest Expense, Net			0.35						0.43
Total (1)			$	21.29					$	20.37

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

The primary factors impacting the cost components of per-unit rates of lease and well, GP&T, DD&A, G&A, and interest expense, net for the nine months ended September 30, 2024, compared to the same period of 2023 are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

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Lease and well expenses of $1,178 million for the first nine months of 2024 increased $102 million from $1,076 million for the same prior year period primarily due to increased operating and maintenance costs ($71 million), increased lease and well administrative expenses ($19 million) and increased workover expenditures ($14 million), all in the United States. Lease and well expenses increased in the United States primarily due to increased operating activities resulting from increased production.

GP&T costs of $1,281 million for the first nine months of 2024 increased $84 million from $1,197 million for the same prior year period primarily due to increased GP&T costs related to increased production in the Permian Basin and Utica.

DD&A expenses for the first nine months of 2024 increased $527 million to $3,089 million from $2,562 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first nine months of 2024 were $502 million higher than the same prior year period. The increase primarily reflects increased production in the United States ($185 million) and in Trinidad ($18 million), and increased unit rates in the United States ($147 million) and in Trinidad ($30 million). In addition, the recording of an adjustment to DD&A ($117 million) primarily related to natural gas production used by EOG's domestic gathering systems also contributed to the variance. DD&A expenses associated with other property, plant and equipment for the first nine months of 2024 were $25 million higher than the same prior year period primarily due to an increase in expenses related to GP&T assets and equipment.

G&A expenses of $480 million for the first nine months of 2024 increased $32 million from $448 million for the same prior year period primarily due to increased employee-related costs ($20 million), professional and other services costs ($9 million) and information systems costs ($8 million).

Interest expense, net of $100 million for the first nine months of 2024 decreased $13 million compared to the same prior year period primarily due to higher capitalized interest ($8 million) and the repayment in March 2023 of the $1,250 million aggregate principal amount of 2.625% Senior Notes due 2023 ($7 million).

Exploration costs of $122 million for the first nine months of 2024 decreased $18 million from $140 million for the same prior year period due primarily to decreased geological and geophysical expenditures ($27 million), partially offset by increased administrative expenses ($6 million) and delay rentals ($3 million).

The following table sets forth impairments for the nine-month periods ended September 30, 2024 and 2023 (in millions):

			Nine Months Ended September 30,
			2024						2023
Proved properties			$	36					$	26
Unproved properties			48						95
Other assets			30						—
Firm commitment contracts			1						2
Total			$	115					$	123

Taxes other than income for the first nine months of 2024 decreased $25 million to $958 million (7.2% of wellhead revenues) from $983 million (7.7% of wellhead revenues) for the same prior year period. The decrease in taxes other than income was primarily due to increased state severance tax refunds ($30 million) and decreased ad valorem/property taxes ($21 million), partially offset by increased severance/production taxes ($24 million), all in the United States.

Other income, net of $204 million for the first nine months of 2024 increased $36 million from $168 million for the same prior year period. The increase was primarily due to increased interest income.

Income taxes of $1,442 million for the first nine months of 2024 decreased from income taxes of $1,548 million for the first nine months of 2023 primarily due to decreased pretax income. The net effective tax rate for the first nine months of 2024 was unchanged from the prior year rate of 22%.

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Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the nine months ended September 30, 2024, were funds generated from operations and, to a lesser extent, net cash received from settlements of financial commodity derivative contracts. The primary uses of cash were exploration and development expenditures; funds used in operations; dividend payments to stockholders; purchases of treasury stock; and other property, plant and equipment expenditures. During the first nine months of 2024, EOG's cash balance increased $844 million to $6,122 million from $5,278 million at December 31, 2023.

Net cash provided by operating activities of $9,380 million for the first nine months of 2024 increased $1,144 million compared to the same period of 2023 primarily due to an increase in wellhead revenues ($450 million), a decrease in net cash used in working capital and other assets and liabilities ($450 million), an increase in net cash received from settlements of financial commodity derivative contracts ($325 million), and a decrease in net cash paid for income taxes ($289 million), partially offset by the return of cash collateral posted for financial commodity derivative contracts in the first nine months of 2023 ($324 million) and an increase in cash operating expenses ($153 million).

Net cash used in investing activities of $4,691 million for the first nine months of 2024 decreased $150 million compared to the same period of 2023 due to a decrease in cash used in working capital associated with investing activities ($610 million), partially offset by an increase in additions to other property, plant and equipment ($264 million), a decrease in proceeds from the sale of assets ($116 million) and an increase in additions to oil and gas properties ($80 million).

Net cash used in financing activities of $3,845 million for the first nine months of 2024 included purchases of treasury stock ($2,253 million), cash dividend payments ($1,578 million) and repayment of finance lease liabilities ($25 million). Net cash used in financing activities of $4,041 million for the first nine months of 2023 included cash dividend payments ($2,041 million), repayments of long-term debt ($1,250 million), purchases of treasury stock ($728 million) and repayment of finance lease liabilities ($24 million).

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Total Expenditures. For the full-year 2024, EOG's updated budget for exploration and development and other property, plant and equipment expenditures is estimated to range from approximately $6.1 billion to $6.3 billion, including exploration and development drilling, facilities, leasehold acquisitions, capitalized interest, dry hole costs and other property, plant and equipment and excluding property acquisitions, asset retirement costs, non-cash exchanges and transactions and exploration costs incurred as operating expenses. The table below sets out components of total expenditures for the nine-month periods ended September 30, 2024 and 2023 (in millions):

			Nine Months Ended September 30,
			2024						2023
Expenditure Category
Capital
Exploration and Development Drilling (1)			$	3,512					$	3,619
Facilities			430						373
Leasehold Acquisitions (2)			205						153
Property Acquisitions (3)			26						9
Capitalized Interest			32						24
Subtotal			4,205						4,178
Exploration Costs			122						140
Dry Hole Costs			6						1
Exploration and Development Expenditures			4,333						4,319
Asset Retirement Costs (4)			(28)						227
Total Exploration and Development Expenditures			4,305						4,546
Other Property, Plant and Equipment (5)			902						638
Total Expenditures			$	5,207					$	5,184

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

(2)    Leasehold acquisitions included $82 million and $60 million for the nine-month periods ended September 30, 2024 and 2023, respectively, related to non-cash property exchanges.

(3)    Property acquisitions included $24 million and $9 million for the nine-month periods ended September 30, 2024 and 2023, respectively, related to non-cash property exchanges.

(4)    Asset Retirement Costs for the nine-month period ended September 30, 2024 included a downward revision to asset retirement obligations of $84 million.

(5)    Other Property, Plant and Equipment included $137 million related to the acquisition of a gathering system in South Texas and $134 million related to the acquisition of a gathering and processing system in the Powder River Basin for the nine-month periods ended September 30, 2024 and 2023, respectively.

Exploration and development expenditures of $4,333 million for the first nine months of 2024 were $14 million higher than the same period of 2023 primarily due to increased facilities expenditures ($57 million) and increased leasehold acquisitions ($52 million), partially offset by decreased development drilling expenditures ($92 million). Exploration and development expenditures for the first nine months of 2024 of $4,333 million consisted of $3,797 million in development drilling and facilities, $478 million in exploration, $32 million in capitalized interest and $26 million in property acquisitions. Exploration and development expenditures for the first nine months of 2023 of $4,319 million consisted of $3,836 million in development drilling and facilities, $450 million in exploration, $24 million in capitalized interest and $9 million in property acquisitions.

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

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Financial Commodity and Other Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2023 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity and other derivative contracts as accounting hedges and, accordingly, accounts for financial commodity and other derivative contracts using the mark-to-market accounting method, including the Brent linked gas sales contract. Under this accounting method, changes in the fair value of outstanding financial and other derivative instruments are recognized as gains or losses in the period of change and are recorded as Gains on Mark-to-Market Financial Commodity and Other Derivative Contracts on the Condensed Consolidated Statements of Income and Comprehensive Income. The related cash flow impact is reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

The total fair value of EOG's financial commodity and other derivative contracts was reflected on the Condensed Consolidated Balance Sheets at September 30, 2024, as a net asset of $77 million.

As discussed in "Operating Revenues," the net cash received from settlements of financial commodity derivative contracts during the third quarter and first nine months of 2024 was $61 million and $195 million, respectively.

Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the period from January 1, 2024 to October 31, 2024 (closed) and outstanding as of October 31, 2024. Natural gas volumes are presented in MMBtu per day (MMBtud) and prices are presented in dollars per MMBtu ($/MMBtu).

Natural Gas Financial Price Swap Contracts

Contracts Sold

Period

Settlement Index

Volume (MMBtud in thousands)

Weighted Average Price ($/MMBtu)

January - November 2024 (closed)

NYMEX Henry Hub

725

$

3.07

December 2024

NYMEX Henry Hub

725

3.07

January - December 2025

NYMEX Henry Hub

725

3.07

Natural Gas Basis Swap Contracts

Contracts Sold

Period

Settlement Index

Volume (MMBtud in thousands)

Weighted Average Price Differential  ($/MMBtu)

January - October 2024 (closed)

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

10

$

0.00

November - 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.

In connection with its financial commodity derivative contracts, EOG had no collateral posted and no collateral held at November 6, 2024. The amount of posted collateral will increase or decrease based on fluctuations in forward NYMEX Henry Hub prices.

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Natural Gas Sales Linked to Brent Crude Oil. In February 2024, EOG entered into a 10-year agreement, commencing in 2027, to sell 180,000 MMBtud of its domestic natural gas production, with 140,000 MMBtud to be sold at a price indexed to Brent and the remaining volumes to be sold at a price indexed to Brent or a U.S. Gulf Coast gas index. It was determined that this agreement meets the definition of a derivative under the Derivatives and Hedging Topic of the Accounting Standards Codification and does not qualify for the normal purchases and normal sales scope exception. As such, this agreement is accounted for as a derivative using the mark-to-market accounting method. Changes in the fair value are recognized as gains or losses in the period of change on the Condensed Consolidated Statements of Income and Comprehensive Income.

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Information Regarding Forward-Looking Statements

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

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

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

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

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

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

•security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, physical breaches of our facilities and other infrastructure or breaches of the information technology systems, facilities and infrastructure of third parties with which we transact business, and enhanced regulatory focus on prevention and disclosure requirements relating to cyber incidents;

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

•the duration and economic and financial impact of epidemics, pandemics or other public health issues;

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

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

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

•the other factors described under ITEM 1A, Risk Factors of EOG's Annual Report on Form 10-K for the year ended December 31, 2023, and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.

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

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PART I.  FINANCIAL INFORMATION

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

EOG RESOURCES, INC.

EOG's exposure to commodity price risk, interest rate risk and foreign currency exchange rate risk is discussed in (i) the "Financial Commodity Derivative Transactions," "Financing" and "Outlook" sections of "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" included in EOG's Annual Report on Form 10-K for the year ended December 31, 2023, filed on February 22, 2024 (EOG's 2023 Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements included in EOG's 2023 Annual Report. For updated information regarding EOG's financial commodity and other derivative contracts and physical commodity contracts, see (i) Note 12, "Risk Management Activities" to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q; (ii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Operating Revenues" in this Quarterly Report on Form 10-Q; and (iii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity - Financial Commodity and Other Derivative Transactions" in this Quarterly Report on Form 10-Q.

ITEM 4. CONTROLS AND PROCEDURES

EOG RESOURCES, INC.

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

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

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PART II. OTHER INFORMATION

EOG RESOURCES, INC.

ITEM 1.    LEGAL PROCEEDINGS

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

Item 103 of Regulation S-K promulgated under the Securities Exchange Act of 1934 (as amended, Exchange Act) requires disclosure regarding certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that EOG reasonably believes will exceed a specified threshold. Pursuant to such item, EOG will be using a threshold of $1 million for purposes of determining whether disclosure of any such proceedings is required. EOG believes proceedings under this threshold are not material to EOG's business and financial condition (the choice of this threshold does not imply that matters with potential monetary sanctions in excess of $1 million are necessarily material to EOG's business or financial condition). Applying this threshold, there are no environmental proceedings to disclose for the quarter ended September 30, 2024.

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

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

Period						Total Number of Shares Purchased (1)						Average Price Paid Per Share						Total Value of Shares Purchased as Part of Publicly Announced Plans or Programs (2)						Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (2)(3)
July 1, 2024 - July 31, 2024						809,797						$	124.95					$	99,999,963					$	2,488,730,725
August 1, 2024 - August 31, 2024						1,866,846						125.82						233,822,313						2,254,908,412
September 1, 2024 - September 30, 2024						3,796,035						121.10						423,737,349						1,831,171,063
Total						6,472,678						122.94						$	757,559,625

(1)Includes 6,161,618 shares repurchased during the quarter ended September 30, 2024, at an average price of $122.95 per share (inclusive of commissions and transaction fees), pursuant to the Share Repurchase Authorization (as defined and further discussed below); such repurchases count against the Share Repurchase Authorization. The share repurchases effected during the period July 1, 2024 through August 1, 2024 were made pursuant to a Rule 10b5-1 trading plan entered into by EOG on June 28, 2024. Also includes 311,060 total shares that were withheld by or returned to EOG during the quarter ended September 30, 2024, at an average price of $122.86 per share, (i) in satisfaction of tax withholding obligations that arose upon the exercise of employee stock options or stock-settled stock appreciation rights or the vesting of restricted stock, restricted stock unit or performance unit grants or (ii) in payment of the exercise price of employee stock options (such shares do not count against the Share Repurchase Authorization).

(2)In November 2021, EOG's Board of Directors (Board) established a new share repurchase authorization that allows for the repurchase by EOG of up to $5 billion of its common stock (Share Repurchase Authorization). As of September 30, 2024, (i) EOG had repurchased an aggregate 26,680,275 shares at a total cost of $3,168,828,937 (inclusive of commissions and transaction fees) under the Share Repurchase Authorization and (ii) an additional $1,831,171,063 of shares remained available for repurchases under the Share Repurchase Authorization. Subsequent to September 30, 2024, the Board increased the Share Repurchase Authorization from $5 billion to $10 billion, effective November 7, 2024.

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

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ITEM 5. OTHER INFORMATION

Trading Plans/Arrangements. On August 30, 2024, Jeffrey R. Leitzell, EOG's Executive Vice President and Chief Operating Officer, adopted a written Rule 10b5-1 trading arrangement in respect of EOG's common stock that is intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) promulgated under the Securities Exchange Act of 1934 (as amended). The arrangement, which was adopted at a time when Mr. Leitzell was not in possession of material, non-public information regarding EOG, provides for the sale by Mr. Leitzell of:

(1)    up to 15,704 shares currently held by Mr. Leitzell;

(2)    55% of the net shares to be received by Mr. Leitzell upon the vesting of 5,665 shares of restricted stock previously granted to him;

(3)    65% of the net shares to be received by Mr. Leitzell upon the vesting of 4,841 shares of restricted stock previously granted to him; and

(4)    the net shares to be received by Mr. Leitzell in connection with the exercise of 8,190 stock-settled stock appreciation rights (SARs) previously granted to him;

in each case, during the specific time periods and subject to the limit price (i.e., trigger price) conditions set forth in the arrangement (and, in the case of the grants of restricted stock and SARs, subject to EOG's withholding of shares in satisfaction of the tax withholding obligations arising upon such vestings and exercise). Mr. Leitzell's Rule 10b5-1 trading arrangement will commence following the applicable cooling-off period and will terminate upon the earlier of (i) the completion of all sales specified in the trading arrangement and (ii) December 31, 2026.

During the quarter ended September 30, 2024, no other Section 16 officer of EOG, and no director of EOG, adopted or terminated any Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (in each case, as defined in Item 408(a) of Regulation S-K).

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ITEM 6.  EXHIBITS

Exhibit No.						Description
3.1(a)			-			Restated Certificate of Incorporation, dated September 3, 1987 (incorporated by reference to Exhibit 3.1(a) to EOG's Annual Report on Form 10-K for the year ended December 31, 2008) (SEC File No. 001-09743).
3.1(b)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 5, 1993 (incorporated by reference to Exhibit 4.1(b) to EOG's Registration Statement on Form S-8, SEC File No. 33-52201, filed February 8, 1994).
3.1(c)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated June 14, 1994 (incorporated by reference to Exhibit 4.1(c) to EOG's Registration Statement on Form S-8, SEC File No. 33-58103, filed March 15, 1995).
3.1(d)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated June 11, 1996 (incorporated by reference to Exhibit 3(d) to EOG's Registration Statement on Form S-3, SEC File No. 333-09919, filed August 9, 1996).
3.1(e)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 7, 1997 (incorporated by reference to Exhibit 3(e) to EOG's Registration Statement on Form S-3, SEC File No. 333-44785, filed January 23, 1998).
3.1(f)			-			Certificate of Ownership and Merger Merging EOG Resources, Inc. into Enron Oil & Gas Company, dated August 26, 1999 (incorporated by reference to Exhibit 3.1(f) to EOG's Annual Report on Form 10-K for the year ended December 31, 1999) (SEC File No. 001-09743).
3.1(g)			-			Certificate of Designations of Series E Junior Participating Preferred Stock, dated February 14, 2000 (incorporated by reference to Exhibit 2 to EOG's Registration Statement on Form 8-A, SEC File No. 001-09743, filed February 18, 2000).
3.1(h)			-			Certificate of Elimination of the Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series A, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(j) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).
3.1(i)			-			Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series C, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(k) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).
3.1(j)			-			Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series D, dated February 24, 2005 (incorporated by reference to Exhibit 3.1(k) to EOG's Annual Report on Form 10-K for the year ended December 31, 2004) (SEC File No. 001-09743).
3.1(k)			-			Amended Certificate of Designations of Series E Junior Participating Preferred Stock, dated March 7, 2005 (incorporated by reference to Exhibit 3.1(m) to EOG's Annual Report on Form 10-K for the year ended December 31, 2007) (SEC File No. 001-09743).
3.1(l)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 3, 2005 (incorporated by reference to Exhibit 3.1(l) to EOG's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005) (SEC File No. 001-09743).
3.1(m)			-			Certificate of Elimination of Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series B, dated March 6, 2008 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed March 6, 2008) (SEC File No. 001-09743).
3.1(n)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated April 28, 2017 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed May 2, 2017) (SEC File No. 001-09743).
3.2			-			Bylaws, dated August 23, 1989, as amended and restated effective as of February 23, 2023 (incorporated by reference to Exhibit 3.2(b) to EOG's Annual Report on Form 10-K for the year ended December 31, 2022) (SEC File No. 001-09743).
10.1			-			Form of Restricted Stock Unit with Performance-Based Conditions ("Performance Unit") Award Agreement for EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (applicable to grants made on or after September 27, 2024).

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Exhibit No.						Description
31.1			-			Section 302 Certification of Periodic Report of Principal Executive Officer.
31.2			-			Section 302 Certification of Periodic Report of Principal Financial Officer.
32.1			-			Section 906 Certification of Periodic Report of Principal Executive Officer.
32.2			-			Section 906 Certification of Periodic Report of Principal Financial Officer.
101.INS			-			Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101.SCH			-			Inline XBRL Schema Document.
*101.CAL			-			Inline XBRL Calculation Linkbase Document.
*101.DEF			-			Inline XBRL Definition Linkbase Document.
*101.LAB			-			Inline XBRL Label Linkbase Document.
*101.PRE			-			Inline XBRL Presentation Linkbase Document.
104			-			Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three Months and Nine Months Ended September 30, 2024 and 2023, (ii) the Condensed Consolidated Balance Sheets - September 30, 2024 and December 31, 2023, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three Months and Nine Months Ended September 30, 2024 and 2023, (iv) the Condensed Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2024 and 2023 and (v) the Notes to Condensed Consolidated Financial Statements.

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SIGNATURES

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

									EOG RESOURCES, INC.
									(Registrant)
Date:			November 7, 2024			By:			/s/ ANN D. JANSSEN Ann D. Janssen Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

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