EOG Resources 10-Q 2022-03-31

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM			10-Q

(Mark One)

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

For the quarterly period ended March 31, 2022

or

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

Commission File Number: 1-9743

EOG RESOURCES, INC.

(Exact name of registrant as specified in its charter)

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

1111 Bagby, Sky Lobby 2, Houston, Texas 77002

(Address of principal executive offices) (Zip Code)

713-651-7000

(Registrant's telephone number, including area code)

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

Title of each class			Trading symbol(s)			Name of each exchange on which registered
Common Stock, par value $0.01 per share			EOG			New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

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

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

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

Smaller reporting company ☐ Emerging growth company ☐

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

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

Yes ☐ No ☒

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

Title of each class						Number of shares
Common Stock, par value $0.01 per share						585,713,473			(as of April 28, 2022)

EOG RESOURCES, INC.

TABLE OF CONTENTS

PART I.			FINANCIAL INFORMATION						Page No.
			ITEM 1.			Financial Statements (Unaudited)
						Condensed Consolidated Statements of Income and Comprehensive Income - Three Months Ended March 31, 2022 and 2021			3
						Condensed Consolidated Balance Sheets - March 31, 2022 and December 31, 2021			4
						Condensed Consolidated Statements of Stockholders' Equity - Three Months Ended March 31, 2022 and 2021			5
						Condensed Consolidated Statements of Cash Flows - Three Months Ended March 31, 2022 and 2021			6
						Notes to Condensed Consolidated Financial Statements			7
			ITEM 2.			Management's Discussion and Analysis of Financial Condition and Results of Operations			21
			ITEM 3.			Quantitative and Qualitative Disclosures About Market Risk			34
			ITEM 4.			Controls and Procedures			34
PART II.			OTHER INFORMATION
			ITEM 1.			Legal Proceedings			35
			ITEM 2.			Unregistered Sales of Equity Securities and Use of Proceeds			35
			ITEM 4.			Mine Safety Disclosures			35
			ITEM 6.			Exhibits			36
SIGNATURES									38

-2-

PART I. FINANCIAL INFORMATION

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(In Millions, Except Per Share Data)

(Unaudited)

			Three Months Ended March 31,
			2022						2021
Operating Revenues and Other
Crude Oil and Condensate			$	3,889					$	2,251
Natural Gas Liquids			681						314
Natural Gas			716						625
Losses on Mark-to-Market Financial Commodity Derivative Contracts			(2,820)						(367)
Gathering, Processing and Marketing			1,469						848
Gains (Losses) on Asset Dispositions, Net			25						(6)
Other, Net			23						29
Total			3,983						3,694
Operating Expenses
Lease and Well			318						270
Transportation Costs			228						202
Gathering and Processing Costs			144						139
Exploration Costs			45						33
Dry Hole Costs			3						11
Impairments			55						44
Marketing Costs			1,283						838
Depreciation, Depletion and Amortization			847						900
General and Administrative			124						110
Taxes Other Than Income			390						215
Total			3,437						2,762
Operating Income			546						932
Other Expense, Net			(1)						(4)
Income Before Interest Expense and Income Taxes			545						928
Interest Expense, Net			48						47
Income Before Income Taxes			497						881
Income Tax Provision			107						204
Net Income			$	390					$	677
Net Income Per Share
Basic			$	0.67					$	1.17
Diluted			$	0.67					$	1.16
Average Number of Common Shares
Basic			582						580
Diluted			586						583
Comprehensive Income
Net Income			$	390					$	677
Other Comprehensive Loss
Foreign Currency Translation Adjustments			(1)						(2)
Other, Net of Tax			—						—
Other Comprehensive Loss			(1)						(2)
Comprehensive Income			$	389					$	675

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

-3-

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Millions, Except Share Data)

(Unaudited)

			March 31, 2022						December 31, 2021
ASSETS
Current Assets
Cash and Cash Equivalents			$	4,009					$	5,209
Accounts Receivable, Net			3,213						2,335
Inventories			586						584
Other			671						456
Total			8,479						8,584
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)			65,408						67,644
Other Property, Plant and Equipment			4,801						4,753
Total Property, Plant and Equipment			70,209						72,397
Less: Accumulated Depreciation, Depletion and Amortization			(41,747)						(43,971)
Total Property, Plant and Equipment, Net			28,462						28,426
Deferred Income Taxes			13						11
Other Assets			1,143						1,215
Total Assets			$	38,097					$	38,236
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts Payable			$	2,660					$	2,242
Accrued Taxes Payable			1,130						518
Dividends Payable			436						436
Liabilities from Price Risk Management Activities			260						269
Current Portion of Long-Term Debt			1,283						37
Current Portion of Operating Lease Liabilities			223						240
Other			272						300
Total			6,264						4,042
Long-Term Debt			3,816						5,072
Other Liabilities			2,191						2,193
Deferred Income Taxes			4,286						4,749
Commitments and Contingencies (Note 8)
Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 585,944,344 Shares Issued at March 31, 2022 and 585,521,512 Shares Issued at December 31, 2021			206						206
Additional Paid in Capital			6,095						6,087
Accumulated Other Comprehensive Loss			(13)						(12)
Retained Earnings			15,283						15,919
Common Stock Held in Treasury, 290,472 Shares at March 31, 2022 and 257,268 Shares at December 31, 2021			(31)

Showing the first 8K of 67K characters. Open the full section

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EOG RESOURCES, INC.

Overview

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

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

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

For the first three months of 2022, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were $94.38 per barrel and $4.91 per million British thermal units (MMBtu), respectively, representing increases of 63% and 83%, respectively, from the average NYMEX prices for the same period in 2021. Market prices for NGLs are influenced by the components extracted, including ethane, propane and butane and natural gasoline, among others, and the respective market pricing for each component.

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

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

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

-21-

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

EOG continues to make progress on the design and fabrication of a platform and related facilities for its previously announced discovery in the Modified U(a) Block. In 2022, EOG expects to install the platform together with the related facilities and drill three development wells and one exploratory well.

Other International. In Australia, in November 2021, a subsidiary of EOG was granted an exploration permit for the WA-488-P Block, located offshore Western Australia. In 2022, EOG continues to prepare for the drilling of an exploration well which is expected to commence in 2023.

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

2022 Capital and Operating Plan**.** Total 2022 capital expenditures are estimated to range from approximately $4.3 billion to $4.7 billion, including facilities and gathering, processing and other expenditures, and excluding acquisitions, non-cash transactions and exploration costs. EOG plans to continue to focus a substantial portion of its exploration and development expenditures in its major producing areas in the United States. In particular, EOG will be focused on United States drilling activity in the Delaware Basin, Eagle Ford oil play, Rocky Mountain area and Dorado gas play where it generates its highest rates-of-return. To further enhance the economics of these plays, EOG expects to continue to improve well performance and to mitigate recent inflationary pressure on operating costs (e.g., costs for fuel and tubulars) through efficiency gains. Full-year 2022 total crude oil, NGLs and natural gas production is expected to return to prepandemic levels. In addition, EOG expects to spend a portion of its anticipated 2022 capital expenditures on leasing acreage, evaluating new prospects, long-term transportation infrastructure and environmental projects.

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

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

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

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

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

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

-22-

Cash Return Framework. Also on May 5, 2022, EOG announced the addition of quantitative guidance to its cash return framework - specifically, a commitment to return a minimum of 60% of annual free cash flow to stockholders, through a combination of quarterly dividends, special dividends and share repurchases. Free cash flow (which is a non-GAAP measure) is computed as EOG's net cash provided by operating activities (a GAAP measure) before certain balance sheet-related changes, less total capital expenditures (a non-GAAP measure). For related discussion regarding our payment of dividends, see ITEM 1A, Risk Factors, and ITEM 5, Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities, of EOG's Annual Report on Form 10-K for the year ended December 31, 2021, filed on February 24, 2022.

Results of Operations

The following review of operations for the three months ended March 31, 2022 and 2021 should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form 10-Q.

Three Months Ended March 31, 2022 vs. Three Months Ended March 31, 2021

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

-23-

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

			Three Months Ended March 31,
			2022									2021
Crude Oil and Condensate Volumes (MBbld) (1)
United States			449.4									428.7
Trinidad			0.7									2.2
Other International (2)			—									0.1
Total			450.1									431.0
Average Crude Oil and Condensate Prices ($/Bbl) (3)
United States			$	96.02								$	58.07
Trinidad			83.82									49.77
Other International (2)			—									38.61
Composite			96.00									58.02
Natural Gas Liquids Volumes (MBbld) (1)
United States			190.3									124.3
Total			190.3									124.3
Average Natural Gas Liquids Prices ($/Bbl) (3)
United States			$	39.77								$	28.03
Composite			39.77									28.03
Natural Gas Volumes (MMcfd) (1)
United States			1,249									1,100
Trinidad			209									217
Other International (2)			—									25
Total			1,458									1,342
Average Natural Gas Prices ($/Mcf) (3)
United States			$	5.81								$	5.52
Trinidad			3.36									3.38
Other International (2)			—									5.66
Composite			5.46									5.17
Crude Oil Equivalent Volumes (MBoed) (4)
United States			847.8									736.4
Trinidad			35.5									38.5
Other International (2)			—									4.0
Total			883.3									778.9
Total MMBoe (4)			79.5									70.1

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

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

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

(4)Thousand barrels of oil equivalent per day or million barrels of oil equivalent, 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.

-24-

Wellhead crude oil and condensate revenues for the first quarter of 2022 increased $1,638 million, or 73%, to $3,889 million from $2,251 million for the same period of 2021. The increase was due to a higher composite average price ($1,539 million) and an increase of 19.1 MBbld, or 4%, in wellhead crude oil and condensate production ($99 million). Increased production was primarily in the Permian Basin, partially offset by decreased production in the Eagle Ford oil play and the Rocky Mountain area. EOG's composite wellhead crude oil and condensate price for the first quarter of 2022 increased 65% to $96.00 per barrel compared to $58.02 per barrel for the same period of 2021.

NGL revenues for the first quarter of 2022 increased $367 million, or 117%, to $681 million from $314 million for the same period of 2021 due to a higher composite average price ($202 million) and an increase of 66.0 MBbld, or 53%, in NGL deliveries ($165 million). Increased production was primarily in the Permian Basin. EOG's composite NGL price for the first quarter of 2022 increased 42% to $39.77 per barrel compared to $28.03 per barrel for the same period of 2021.

Wellhead natural gas revenues for the first quarter of 2022 increased $91 million, or 15%, to $716 million from $625 million for the same period of 2021. The increase was due to an increase in natural gas deliveries ($53 million) and a higher average composite price ($38 million). Natural gas deliveries for the first quarter of 2022 increased 116 MMcfd, or 9%, compared to the same period of 2021 due primarily to increased production of associated natural gas from the Permian Basin and higher deliveries in the Dorado gas play, partially offset by lower natural gas volumes associated with the disposition of the China assets in the second quarter of 2021. EOG's composite wellhead natural gas price for the first quarter of 2022 increased 6% to $5.46 per Mcf compared to $5.17 per Mcf for the same period of 2021.

During the first quarter of 2022, EOG recognized net losses on the mark-to-market of financial commodity derivative contracts of $2,820 million compared to net losses of $367 million for the same period of 2021. During the first quarter of 2022, net cash paid for settlements of financial commodity derivative contracts was $296 million compared to net cash paid for settlements of financial commodity derivative contracts of $30 million for the same period of 2021.

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

Gathering, processing and marketing revenues less marketing costs for the first quarter of 2022 increased $176 million as compared to the same period of 2021 primarily due to higher margins on crude oil and natural gas marketing activities.

-25-

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

			Three Months Ended March 31,
			2022						2021
Lease and Well			$	4.00					$	3.85
Transportation Costs			2.87						2.88
Gathering and Processing Costs			1.81						1.98
Depreciation, Depletion and Amortization (DD&A) -
Oil and Gas Properties			10.19						12.31
Other Property, Plant and Equipment			0.46						0.53
General and Administrative (G&A)			1.56						1.57
Interest Expense, Net			0.60						0.67
Total (1)			$	21.49					$	23.79

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

The primary factors impacting the cost components of per-unit rates of lease and well, transportation costs, gathering and processing costs, DD&A and G&A for the three months ended March 31, 2022, compared to the same period of 2021, are set forth below. See "Operating Revenues and Other" above for a discussion of wellhead volumes.

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

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

Lease and well expenses of $318 million for the first quarter of 2022 increased $48 million from $270 million for the same prior year period primarily due to increased operating and maintenance costs ($35 million) and increased workovers expenditures ($11 million), both in the United States. Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

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

Transportation costs of $228 million for the first quarter of 2022 increased $26 million from $202 million for the same prior year period primarily due to increased transportation costs related to production from the Permian Basin ($20 million), the Eagle Ford oil play ($5 million) and the Rocky Mountain area ($4 million).

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

-26-

Gathering and processing costs increased $5 million to $144 million for the first quarter of 2022 compared to $139 million for the same prior year period primarily due to increased gathering and processing fees ($16 million) and operating and maintenance expense ($8 million), both related to production from the Permian Basin; partially offset by decreased gathering and processing fees in the Eagle Ford oil play ($9 million) and decreased operating and maintenance expenses in the Eagle Ford oil play ($6 million) and the Rocky Mountain area ($4 million).

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

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

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

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

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

-27-

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

			Three Months Ended March 31,
			2022						2021
Proved properties			$	1					$	—
Unproved properties			54						43
Firm commitment contracts			—						1
Total			$	55					$	44

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

Taxes other than income for the first quarter of 2022 increased $175 million to $390 million (7.4% of wellhead revenues) from $215 million (6.7% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased severance/production taxes ($131 million), increased ad valorem/property taxes ($38 million) and increased payroll taxes ($6 million), all in the United States.

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

Capital Resources and Liquidity

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

Net cash provided by operating activities of $828 million for the first three months of 2022 decreased $1,042 million compared to the same period of 2021 primarily due to an increase in collateral posted for financial commodity derivative contracts ($2,275), net cash used in working capital and other assets and liabilities in the first three months of 2022 ($891 million) compared to net cash used in working capital and other assets and liabilities in the first three months of 2021 ($352 million), an increase in net cash paid for settlements of financial commodity derivative contracts ($266 million) and an increase in cash operating expenses ($264 million), partially offset by an increase in wellhead revenues ($2,096 million) and an increase in gathering, processing and marketing revenues less marketing costs ($176 million).

Net cash used in investing activities of $956 million for the first three months of 2022 increased $135 million compared to the same period of 2021 due to net cash used in working capital associated with investing activities in the first three months of 2022 ($68 million) compared to net cash provided by working capital associated with investing activities in the first three months of 2021 ($91 million), an increase in additions to oil and gas properties ($64 million) and an increase in additions to other property, plant and equipment ($28 million), partially offset by an increase in proceeds from the sale of assets ($116 million).

-28-

Net cash used in financing activities of $1,072 million for the first three months of 2022 included cash dividend payments ($1,023 million), purchases of treasury stock in connection with stock compensation plans ($43 million) and repayment of finance lease liabilities ($10 million). Net cash used in financing activities of $988 million for the first three months of 2021 included repayments of long-term debt ($750 million), cash dividend payments ($219 million), purchases of treasury stock in connection with stock compensation plans ($10 million) and repayment of finance lease liabilities ($9 million).

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

			Three Months Ended March 31,
			2022						2021
Expenditure Category
Capital
Exploration and Development Drilling			$	813					$	733
Facilities			109						82
Leasehold Acquisitions (1)			64						58
Property Acquisitions (2)			5						9
Capitalized Interest			8						8
Subtotal			999						890
Exploration Costs			45						33
Dry Hole Costs			3						11
Exploration and Development Expenditures			1,047						934
Asset Retirement Costs			27						17
Total Exploration and Development Expenditures			1,074						951
Other Property, Plant and Equipment (3)			70						116
Total Expenditures			$	1,144					$	1,067

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

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

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

Exploration and development expenditures of $1,047 million for the first three months of 2022 were $113 million higher than the same period of 2021 primarily due to increased exploration and development drilling expenditures in the United States ($94 million), increased facilities expenditures ($27 million) and increased leasehold acquisitions ($6 million), partially offset by decreased exploration and development expenditures in Trinidad ($9 million) and Other International ($5 million). Exploration and development expenditures for the first three months of 2022 of $1,047 million consisted of $907 million in development drilling and facilities, $127 million in exploration, $8 million in capitalized interest and $5 million in property acquisitions. Exploration and development expenditures for the first three months of 2021 of $934 million consisted of $812 million in development drilling and facilities, $105 million in exploration, $9 million in property acquisitions and $8 million in capitalized interest.

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

-29-

Financial Commodity Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's Annual Report on Form 10-K for the year ended December 31, 2021, filed on February 24, 2022, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as Gains (Losses) on Mark-to-Market Financial Commodity Derivative Contracts on the Condensed Consolidated Statements of Income and Comprehensive Income. The related cash flow impact is reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

The total fair value of EOG's financial commodity derivative contracts, net of associated collateral posted, was reflected on the Condensed Consolidated Balance Sheets at March 31, 2022, as a net liability of $370 million.

Presented below is a comprehensive summary of EOG's financial commodity derivative contracts settled during the period from January 1, 2022 to May 4, 2022 (closed) and outstanding as of May 4, 2022. Crude oil and NGL volumes are presented in MBbld and prices are presented in $/Bbl. Natural gas volumes are presented in MMBtu per day (MMBtud) and prices are presented in dollars per MMBtu ($/MMBtu).

Crude Oil Financial Price Swap Contracts
												Contracts Sold												Contracts Purchased
Period						Settlement Index						Volume (MBbld)						Weighted Average Price ($/Bbl)						Volume (MBbld)						Weighted Average Price ($/Bbl)
January - March 2022 (closed)						NYMEX West Texas Intermediate (WTI)						140						$	65.58					—						$	—
April 2022 (closed)						NYMEX WTI						140						65.62						—						—
May - June 2022						NYMEX WTI						140						65.62						—						—
July - September 2022						NYMEX WTI						140						65.59						—						—
October - December 2022 (closed) (1)						NYMEX WTI						53						66.11						—						—
October - December 2022						NYMEX WTI						87						65.41						87						88.85
January - March 2023						NYMEX WTI						150						67.92						—						—
April - June 2023						NYMEX WTI						120						67.79						—						—
July - September 2023						NYMEX WTI						100						70.15						—						—
October - December 2023						NYMEX WTI						69						69.41						—						—

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

-30-

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

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

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

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

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

In connection with its financial commodity derivative contracts, EOG had $2,900 million of collateral posted at May 4, 2022. EOG expects this collateral to be applied to the settlement of financial commodity derivative contracts if market prices remain above contract prices. The amount of posted collateral will increase or decrease based on fluctuations in forward NYMEX WTI and Henry Hub prices.

-31-

Information Regarding Forward-Looking Statements

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

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

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

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

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

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

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

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

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

-32-

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

-33-

PART I. FINANCIAL INFORMATION

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," "Foreign Currency Exchange Rate Risk" and "Outlook" sections of "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" included in EOG's Annual Report on Form 10-K for the year ended December 31, 2021, filed on February 24, 2022 (EOG's 2021 Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements included in EOG's 2021 Annual Report. There have been no material changes in this information. For additional information regarding EOG's financial commodity derivative contracts and physical commodity contracts, see (i) Note 12, "Risk Management Activities," to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q; (ii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Operating Revenues and Other" in this Quarterly Report on Form 10-Q; and (iii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity - Financial Commodity Derivative Transactions" in this Quarterly Report on Form 10-Q.

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.

-34-

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, requires disclosure regarding certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that EOG reasonably believes will exceed a specified threshold. Pursuant to recent amendments to this item, EOG will be using a threshold of $1 million for purposes of determining whether disclosure of any such proceedings is required. EOG believes proceedings under this threshold are not material to EOG's business and financial condition. Applying this threshold, there are no environmental proceedings to disclose for the quarter ended March 31, 2022.

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

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

Period						Total Number of Shares Purchased (1)						Average Price Paid Per Share						Total Value of Shares Purchased as Part of Publicly Announced Plans or Programs						Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (2)
January 1, 2022 - January 31, 2022						62,027						$	102.94					—						$	5,000,000,000
February 1, 2022 - February 28, 2022						112,866						112.27						—						$	5,000,000,000
March 1, 2022 - March 31, 2022						195,555						119.05						—						$	5,000,000,000
Total						370,448						114.29						—

(1)The 370,448 total shares for the quarter ended March 31, 2022, consist solely of shares that were withheld by or returned to EOG (i) in satisfaction of tax withholding obligations that arose upon the exercise of employee stock options or stock-settled stock appreciation rights or the vesting of restricted stock, restricted stock unit, or performance unit grants or (ii) in payment of the exercise price of employee stock options. These shares do not count against the November 2021 Authorization (as defined and further discussed below).

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

ITEM 4. MINE SAFETY DISCLOSURES

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

-35-

Exhibit No.						Description
3.1(a)			-			Restated Certificate of Incorporation, dated September 3, 1987 (incorporated by reference to Exhibit 3.1(a) to EOG's Annual Report on Form 10-K for the year ended December 31, 2008) (SEC File No. 001-09743).
3.1(b)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 5, 1993 (incorporated by reference to Exhibit 4.1(b) to EOG's Registration Statement on Form S-8, SEC File No. 33-52201, filed February 8, 1994).
3.1(c)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated June 14, 1994 (incorporated by reference to Exhibit 4.1(c) to EOG's Registration Statement on Form S-8, SEC File No. 33-58103, filed March 15, 1995).
3.1(d)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated June 11, 1996 (incorporated by reference to Exhibit 3(d) to EOG's Registration Statement on Form S-3, SEC File No. 333-09919, filed August 9, 1996).
3.1(e)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 7, 1997 (incorporated by reference to Exhibit 3(e) to EOG's Registration Statement on Form S-3, SEC File No. 333-44785, filed January 23, 1998).
3.1(f)			-			Certificate of Ownership and Merger Merging EOG Resources, Inc. into Enron Oil & Gas Company, dated August 26, 1999 (incorporated by reference to Exhibit 3.1(f) to EOG's Annual Report on Form 10-K for the year ended December 31, 1999) (SEC File No. 001-09743).
3.1(g)			-			Certificate of Designations of Series E Junior Participating Preferred Stock, dated February 14, 2000 (incorporated by reference to Exhibit 2 to EOG's Registration Statement on Form 8-A, SEC File No. 001-09743, filed February 18, 2000).
3.1(h)			-			Certificate of Elimination of the Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series A, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(j) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).
3.1(i)			-			Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series C, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(k) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).
3.1(j)			-			Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series D, dated February 24, 2005 (incorporated by reference to Exhibit 3.1(k) to EOG's Annual Report on Form 10-K for the year ended December 31, 2004) (SEC File No. 001-09743).
3.1(k)			-			Amended Certificate of Designations of Series E Junior Participating Preferred Stock, dated March 7, 2005 (incorporated by reference to Exhibit 3.1(m) to EOG's Annual Report on Form 10-K for the year ended December 31, 2007) (SEC File No. 001-09743).
3.1(l)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated May 3, 2005 (incorporated by reference to Exhibit 3.1(l) to EOG's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005) (SEC File No. 001-09743).
3.1(m)			-			Certificate of Elimination of Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series B, dated March 6, 2008 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed March 6, 2008) (SEC File No. 001-09743).
3.1(n)			-			Certificate of Amendment of Restated Certificate of Incorporation, dated April 28, 2017 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed May 2, 2017) (SEC File No. 001-09743).
3.2			-			Bylaws, dated August 23, 1989, as amended and restated effective as of September 22, 2015 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed September 28, 2015) (SEC File No. 001-09743).

-36-

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.
95			-			Mine Safety Disclosure Exhibit.
101.INS			-			Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101.SCH			-			Inline XBRL Schema Document.
*101.CAL			-			Inline XBRL Calculation Linkbase Document.
*101.DEF			-			Inline XBRL Definition Linkbase Document.
*101.LAB			-			Inline XBRL Label Linkbase Document.
*101.PRE			-			Inline XBRL Presentation Linkbase Document.
104			-			Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

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

-37-

SIGNATURES

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

									EOG RESOURCES, INC.
									(Registrant)
Date:			May 5, 2022			By:			/s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

-38-