EOG Resources Reports Second Quarter 2022 Results, Declares $1.50 per Share Special Dividend and Reiterates Unchanged Full-Year 2022 Capital and Oil Volume Plan

Rhea-AI Summary

EOG Resources reported strong second quarter results for 2022, with total revenue of $7.4 billion and net income of $2.2 billion, translating to a net income per share of $3.81. The company declared a special dividend of $1.50 per share, payable on September 29, 2022. Adjusted net income reached $1.6 billion, generating $1.3 billion in free cash flow. Production volumes exceeded guidance, with crude oil output averaging 464.1 MBod. EOG maintained a robust balance sheet with a debt-to-total capitalization of 18.6% and free cash flow generation amidst rising operational costs.

Positive

• Net income increased to $2.2 billion from $390 million in Q1 2022.
• Special dividend of $1.50 per share declared, totaling $1.5 billion.
• Generated $1.3 billion in free cash flow in Q2 2022.
• Crude oil production exceeded guidance, averaging 464.1 MBod.
• Implemented innovative leak detection system, enhancing environmental monitoring.

Negative

• Adjusted net income decreased from $2.35 billion in Q1 2022 to $1.6 billion.
• Cash operating costs increased slightly, impacting profitability.

HOUSTON, Aug. 4, 2022 /PRNewswire/ -- EOG Resources, Inc. (EOG) today reported second quarter 2022 results. The attached supplemental financial tables and schedules for the reconciliation of non-GAAP measures to GAAP measures and related definitions, along with a related presentation, are also available on EOG's website at http://investors.eogresources.com/investors.

Key Financial Results

In millions of USD, except per-share and ratio data
		2Q 2022		1Q 2022		2Q 2021
GAAP	Total Revenue	7,407		3,983		4,139
	Net Income	2,238		390		907
	Net Income Per Share	3.81		0.67		1.55
	Net Cash Provided by Operating Activities	2,048		828		1,559
	Total Expenditures	1,521		1,144		1,089
	Current and Long-Term Debt	5,091		5,099		5,125
	Cash and Cash Equivalents	3,073		4,009		3,880
	Debt-to-Total Capitalization	18.6 %		19.1 %		19.7 %
Non-GAAP	Adjusted Net Income	1,614		2,346		1,012
	Adjusted Net Income Per Share	2.74		4.00		1.73
	CFO before Changes in Working Capital	2,357		3,372		2,001
	Capital Expenditures	1,071		1,009		937
	Free Cash Flow	1,286		2,363		1,064
	Net Debt	2,018		1,090		1,245
	Net Debt-to-Total Capitalization	8.3 %		4.8 %		5.6 %

Second Quarter 2022 Highlights

• Declared special dividend of $1.50 per share
• Earned adjusted net income of $1.6 billion, or $2.74 per share
• Generated $1.3 billion of free cash flow
• Oil, NGL and natural gas production above guidance midpoints
• Capital expenditures below low end of guidance range
• Total per-unit cash operating costs below guidance midpoint
• Deployed in-house developed continuous leak detection system

Second Quarter 2022 Highlights

Volumes and Capital Expenditures

Wellhead Volumes	2Q 2022		2Q 2022 Guidance Midpoint		1Q 2022		2Q 2021
Crude Oil and Condensate (MBod)	464.1		458.5		450.1		448.6
Natural Gas Liquids (MBbld)	201.9		193.0		190.3		138.5
Natural Gas (MMcfd)	1,528		1,465		1,458		1,445
Total Crude Oil Equivalent (MBoed)	920.7		895.7		883.3		828.0
Capital Expenditures ($MM)	1,071		1,200		1,009		937

From Ezra Yacob, Chief Executive Officer

"EOG delivered another quarter of outstanding operating execution. Our second quarter performance is attributable to the dedication and persistence of our employees and the power of our high-quality inventory across our multi-basin portfolio.

"We are adding reserves at lower finding costs and in turn lowering the overall cost base of the company. The Delaware Basin remains the largest area of activity in the company and is delivering exceptional returns. The Eagle Ford also continues to deliver top-tier results while operating at a steady pace. Our emerging South Texas Dorado dry gas play and Powder River Basin Mowry and Niobrara combo plays are contributing to EOG's success today while laying the groundwork for years of future high-return investment. And our robust exploration pipeline of potential new plays promises to further raise the bar on our performance.

"Our performance this year proves that we have emerged from the downturn better than ever. The company is positioned to deliver significant value to shareholders with our low cost structure and increased exposure to oil and natural gas prices with the recent reductions in our hedge position. This is supported by an industry-leading balance sheet and a regular dividend that allow EOG to deliver significant value through the cycle.

"We are well positioned to carry this momentum into 2023. We have offset a significant portion of inflation this year and are working on plans to identify further cost savings next year. We continue to advance new technology and innovative projects to further lower our environmental footprint, such as an EOG-developed continuous leak detection system that is being deployed at our Delaware Basin facilities. Throughout the year and as we begin to plan for 2023 we remain focused on disciplined capital allocation. Our long-term vision is to be among the lowest cost, highest return and lowest emissions producers, playing a significant role in the long-term future of energy."

Second Quarter 2022 Financial Performance

Adjusted Earnings per Share 2Q 2022 vs 1Q 2022

Prices and Hedges
Crude oil, NGL and natural gas prices increased significantly in 2Q compared with 1Q. Cash paid for hedge settlements in 2Q increased by $1.8 billion compared with 1Q, of which $1.3 billion related to the early termination of certain contracts.

Volumes
Total company crude oil production in 2Q of 464,100 Bopd was above the high end of the guidance range and 3% more than 1Q. NGL and natural gas production were each above the midpoint of the guidance ranges and increased 6% and 5%, respectively, compared with 1Q. Total company equivalent production increased 4% compared with 1Q.

Per-Unit Costs and Other
Cash operating costs declined to $10.12 per BOE in 2Q compared with $10.24 per BOE in 1Q. Lower lease and well cost was the most significant contributor to the reduction. A higher DD&A rate offset the reduction in cash operating costs. Lower marketing margin (gathering, processing and marketing revenue less marketing costs) and higher taxes other than income reduced earnings from other sources in 2Q compared with 1Q.

Change in Cash 2Q 2022 vs 1Q 2022

Free Cash Flow
EOG generated cash flow from operations before changes in working capital of $2.4 billion in 2Q. The company incurred $1.1 billion of cash capital expenditures, resulting in $1.3 billion of free cash flow.

Dividends and Bolt-on Acquisition
EOG paid $1.5 billion in dividends in 2Q, including $1.1 billion of special dividends. Acquisitions and divestitures in 2Q reduced cash by $0.2 billion, primarily related to a bolt-on acquisition in an exploration area and partially offset by sales of non-core assets.

Second Quarter 2022 Operating Performance

Lease and Well
Per-unit LOE costs declined $0.13 in 2Q compared with 1Q and were within the guidance range. The divestiture of legacy gas assets in the Rocky Mountain area and overall efficiency improvements in the Delaware Basin were the largest contributors to the cost reduction.

Transportation, Gathering and Processing
Per-unit transportation and G&P costs in 2Q were in-line with 1Q and slightly below the guidance midpoints.

General and Administrative
Per-unit G&A costs in 2Q were in-line with 1Q but significantly below the guidance midpoint. A transaction expected to occur in 2Q was not executed.

Depreciation, Depletion and Amortization Per-unit DD&A costs in 2Q were slightly above the guidance midpoint and increased 2% compared with 1Q. Facility additions and the divestiture of legacy gas assets contributed to the increase.

Special Dividend and Continuous Methane Monitoring

Special Dividend
The Board of Directors today declared a special dividend of $1.50 per share on EOG's common stock. The special dividend will be payable September 29, 2022, to stockholders of record as of September 15, 2022. Consistent with its past practice for the third quarter regular dividend, the Board will consider the quarterly regular dividend in September.

EOG's iSense^SM Continuous Leak Detection System
EOG has been evaluating continuous methane monitoring technology for several years and initiated a pilot project using an EOG-developed system about 18 months ago, named iSense^SM. The company tested iSense^SM against other monitoring solutions in use and available in the market. The testing confirmed that iSense^SM detects methane release events consistent with other commercial systems. iSense^SM is currently deployed in the Delaware Basin covering about 60% of production. The system will be deployed across additional sites in the Delaware Basin and other operating areas over the remainder of 2022 and in 2023.

As an in-house developed system, iSense^SM enables EOG to integrate the data it collects with existing operational data from EOG's other proprietary systems. This allows for the unique ability to analyze production and facility data to conduct root cause analysis, prioritize resources and dispatch repair measures. EOG expects to learn through analysis of the growing data set collected by iSense^SM how to design and build better facilities and continuously improve its infrastructure.

Second Quarter 2022 Results vs Guidance

(Unaudited)
Crude Oil and Condensate Volumes (MBod)	2Q 2022	2Q 2022 Guidance Midpoint	Variance	1Q 2022	4Q 2021	3Q 2021	2Q 2021
United States	463.5	458.0	5.5	449.4	449.7	448.3	446.9
Trinidad	0.6	0.5	0.1	0.7	0.9	1.2	1.7
Other International	0.0	0.0	0.0	0.0	0.0	0.0	0.0
Total	464.1	458.5	5.6	450.1	450.6	449.5	448.6
Natural Gas Liquids Volumes (MBbld)
Total	201.9	193.0	8.9	190.3	156.9	157.9	138.5
Natural Gas Volumes (MMcfd)
United States	1,324	1,280	44	1,249	1,328	1,210	1,199
Trinidad	204	185	19	209	206	212	233
Other International	0	0	0	0	0	0	13
Total	1,528	1,465	63	1,458	1,534	1,422	1,445
Total Crude Oil Equivalent Volumes (MBoed)	920.7	895.7	25.0	883.3	863.1	844.4	828.0
Total MMBoe	83.8	81.5	2.3	79.5	79.4	77.7	75.3
Benchmark Price
Oil (WTI) ($/Bbl)	108.42			94.38	77.17	70.55	66.06
Natural Gas (HH) ($/Mcf)	7.17			4.91	5.83	4.01	2.83
Crude Oil and Condensate - above (below) WTI ($/Bbl)
United States	2.84	2.80	0.04	1.64	1.14	0.33	0.10
Trinidad	(10.13)	(8.50)	(1.63)	(10.56)	(10.31)	(10.36)	(9.80)
Natural Gas Liquids - Realizations as % of WTI	39.0 %	40.0 %	(1.0 %)	42.1 %	52.4 %	53.5 %	44.1 %
Natural Gas - above (below) NYMEX Henry Hub ($/Mcf)
United States	0.60	0.75	(0.15)	0.90	0.57	0.49	0.16
Natural Gas Realizations ($/Mcf)
Trinidad	3.42	3.40	0.02	3.36	3.48	3.39	3.37
Total Expenditures (GAAP) ($MM)	1,521			1,144	1,137	962	1,089
Capital Expenditures (non-GAAP) ($MM)	1,071	1,200	(129)	1,009	1,015	891	937
Operating Unit Costs ($/Boe)
Lease and Well	3.87	3.80	0.07	4.00	4.09	3.48	3.58
Transportation Costs	2.91	2.95	(0.04)	2.87	2.87	2.82	2.84
Gathering and Processing	1.81	1.90	(0.09)	1.81	1.85	1.87	1.70
General and Administrative	1.53	1.85	(0.32)	1.56	1.75	1.83	1.59
Cash Operating Costs	10.12	10.50	(0.38)	10.24	10.56	10.00	9.71
Depreciation, Depletion and Amortization	10.87	10.80	0.07	10.65	11.46	11.93	12.13
Expenses ($MM)
Exploration and Dry Hole	55	40	15	48	85	48	49
Impairment (GAAP)	91			55	206	82	44
Impairment (excluding certain impairments (non-GAAP))2	55	85	(30)	55	206	69	43
Capitalized Interest	7	8	(1)	8	9	8	8
Net Interest	48	48	0	48	38	48	45
Taxes Other Than Income (% of Wellhead Revenue)	7.3 %	7.0 %	0.3 %	7.4 %	6.8 %	6.8 %	6.9 %
Income Taxes
Effective Rate	22.3 %	22.5 %	(0.2 %)	21.7 %	20.5 %	23.4 %	19.3 %
Current Tax (Benefit) / Expense ($MM)	745	680	65	573	393	446	313

Third Quarter and Full-Year 2022 Guidance³

(Unaudited)
See "Endnotes" below for related discussion and definitions.	3Q 2022 Guidance Range			FY 2022 Guidance Range			2021 Actual	2020 Actual
Crude Oil and Condensate Volumes (MBod)
United States	456.0	-	465.0	458.0	-	463.0	443.4	408.1
Trinidad	0.0	-	1.0	0.4	-	0.6	1.5	1.0
Other International	0.0	-	0.0	0.0	-	0.0	0.1	0.1
Total	456.0	-	466.0	458.4	-	463.6	445.0	409.2
Natural Gas Liquids Volumes (MBbld)
Total	180.0	-	210.0	185.0	-	205.0	144.5	136.0
Natural Gas Volumes (MMcfd)
United States	1,250	-	1,350	1,270	-	1,350	1,210	1,040
Trinidad	135	-	165	175	-	185	217	180
Other International	0	-	0	0	-	0	9	32
Total	1,385	-	1,515	1,445	-	1,535	1,436	1,252
Crude Oil Equivalent Volumes (MBoed)
United States	844.3	-	900.0	854.7	-	893.0	789.6	717.5
Trinidad	22.5	-	28.5	29.6	-	31.4	37.7	30.9
Other International	0.0	-	0.0	0.0	-	0.0	1.6	5.4
Total	866.8	-	928.5	884.3	-	924.4	828.9	753.8
Benchmark Price
Oil (WTI) ($/Bbl)							67.96	39.40
Natural Gas (HH) ($/Mcf)							3.85	2.08
Crude Oil and Condensate Differentials - above (below) WTI4 ($/Bbl)
United States	3.00	-	4.00	2.40	-	2.80	0.58	(0.75)
Trinidad	(10.00)	-	(8.00)	(11.00)	-	(9.00)	(11.70)	(9.20)
Natural Gas Liquids - Realizations as % of WTI
Total	33.0 %	-	43.0 %	36.0 %	-	42.0 %	50.5 %	34.0 %
Natural Gas Differentials - above (below) NYMEX Henry Hub5 ($/Mcf)
United States	0.65	-	1.05	0.85	-	1.00	1.03	(0.47)
Natural Gas Realizations6 ($/Mcf)
Trinidad	7.00	-	7.60	4.00	-	4.50	3.40	2.57
Total Expenditures (GAAP) ($MM)							4,255	4,113
Capital Expenditures7 (non-GAAP) ($MM)	1,150	-	1,350	4,300	-	4,700	3,755	3,344
Operating Unit Costs ($/Boe)
Lease and Well	3.50	-	4.20	3.70	-	4.00	3.75	3.85
Transportation Costs	2.70	-	3.10	2.80	-	3.00	2.85	2.66
Gathering and Processing	1.75	-	1.95	1.80	-	1.90	1.85	1.66
General and Administrative	1.90	-	2.20	1.60	-	1.80	1.69	1.75
Cash Operating Costs	9.85	-	11.45	9.90	-	10.70	10.14	9.92
Depreciation, Depletion and Amortization	10.55	-	11.15	10.65	-	10.95	12.07	12.32
Expenses ($MM)
Exploration and Dry Hole	45	-	55	170	-	210	225	159
Impairment (GAAP)							376	2,100
Impairment (excluding certain impairments (non-GAAP))2	50	-	90	210	-	290	361	232
Capitalized Interest	5	-	10	25	-	35	33	31
Net Interest	42	-	47	180	-	190	178	205
Taxes Other Than Income (% of Wellhead Revenue)	6.0 %	-	8.0 %	7.0 %	-	8.0 %	6.8 %	6.6 %
Income Taxes
Effective Rate	20.0 %	-	25.0 %	20.0 %	-	25.0 %	21.4 %	18.2 %
Current Tax (Benefit) / Expense ($MM)	410	-	510	2,300	-	2,500	1,393	(61)

 

Second Quarter 2022 Results Webcast
Friday, August 5, 2022, 9:00 a.m. Central time (10:00 a.m. Eastern time)
Webcast will be available on EOG's website for one year.
http://investors.eogresources.com/Investors

About EOG
EOG Resources, Inc. (NYSE: EOG) is one of the largest crude oil and natural gas exploration and production companies in the United States with proved reserves in the United States and Trinidad. To learn more visit www.eogresources.com.

Investor Contacts
David Streit 713‐571‐4902
Neel Panchal 713‐571‐4884

Media Contact
Kimberly Ehmer 713‐571‐4676

Endnotes
1)	Includes gathering, processing and marketing revenue, other revenue, marketing costs, taxes other than income, other income (expense), interest expense and the impact of changes in the effective income tax rate.
2)	In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total impairment costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties  not being as productive as it originally estimated).
3)	The forecast items for the third quarter and full year 2022 set forth above for EOG Resources, Inc. (EOG) are  based on current available information and expectations as of the date of the accompanying press release. EOG undertakes no obligation, other than as required by applicable law, to update or revise this forecast, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise. This forecast, which should be read in conjunction with the accompanying press release and EOG's related Current Report on Form 8-K filing, replaces and supersedes any previously issued guidance or forecast.
4)	EOG bases United States and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma, using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month.
5)	EOG bases United States natural gas price differentials upon the natural gas price at Henry Hub, Louisiana, using the simple average of the NYMEX settlement prices for the last three trading days of the applicable month.
6)	The third quarter 2022 realized natural gas price for Trinidad includes a one-time pricing adjustment of approximately $3.50/Mcf for prior-period production following a contract amendment with the National Gas Company of Trinidad and Tobago Limited (NGC).
7)	The forecast includes expenditures for Exploration and Development Drilling, Facilities, Leasehold Acquisitions, Capitalized Interest, Dry Hole Costs and Other Property, Plant and Equipment. The forecast excludes Property Acquisitions, Asset Retirement Costs, Non-Cash Exchanges and Transactions and exploration costs incurred as operating expenses.

 

Glossary
Acq	Acquisitions
ATROR	After-tax rate of return
Bbl	Barrel
Bn	Billion
Boe	Barrels of oil equivalent
Bopd	Barrels of oil per day
CAGR	Compound annual growth rate
Capex	Capital expenditures
CFO	Cash flow provided by operating activities before changes in working capital
CO2e	Carbon dioxide equivalent
DD&A	Depreciation, Depletion and Amortization
Disc	Discoveries
Divest	Divestitures
EPS	Earnings per share
Ext	Extensions
G&A	General and administrative expense
G&P	Gathering and processing expense
GHG	Greenhouse gas
HH	Henry Hub
LOE	Lease operating expense, or lease and well expense
MBbld	Thousand barrels of liquids per day
MBod	Thousand barrels of oil per day
MBoe	Thousand barrels of oil equivalent
MBoed	Thousand barrels of oil equivalent per day
Mcf	Thousand cubic feet of natural gas
MMBoe	Million barrels of oil equivalent
MMcfd	Million cubic feet of natural gas per day
NGLs	Natural gas liquids
OTP	Other than price
NYMEX	U.S. New York Mercantile Exchange
QoQ	Quarter over quarter
Trans	Transportation expense
USD	United States dollar
WTI	West Texas Intermediate
YoY	Year over year
$MM	Million United States dollars
$/Bbl	U.S. Dollars per barrel
$/Boe	U.S. Dollars per barrel of oil equivalent
$/Mcf	U.S. Dollars per thousand cubic feet

This press release may include 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. Furthermore, this press release and any accompanying disclosures may include or reference certain forward‐looking, non‐GAAP financial measures, such as free cash flow and cash flow from operations before changes in working capital, and certain related estimates regarding future performance, results and financial position. Because we provide these measures on a forward‐looking basis, we cannot reliably or reasonably predict certain of the necessary components of the most directly comparable forward‐looking    GAAP measures, such as future changes in working capital. Accordingly, we are unable to present a quantitative reconciliation of such forward‐looking, non‐GAAP financial measures to the respective most directly comparable forward‐looking GAAP financial measures. Management believes these forward‐looking, non‐GAAP measures may be a useful tool for the investment community in comparing EOG's forecasted financial performance to the forecasted financial performance of other companies in the industry. Any such forward‐looking measures and estimates are intended to be illustrative only and are not intended to reflect the results that EOG will necessarily achieve for the period(s) presented; EOG's actual results may differ materially from such measures and estimates.  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;
• 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.

The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only "proved" reserves (i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also "probable" reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as "possible" reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves). Statements of reserves are only estimates and may not correspond to the ultimate quantities of oil and gas recovered. Any reserve or resource estimates provided in this press release that are not specifically designated as being estimates of proved reserves may include "potential" reserves, "resource potential" and/or other estimated reserves or estimated resources not necessarily calculated in accordance with, or contemplated by, the SEC's latest reserve reporting guidelines. Investors are urged to consider closely the disclosure in EOG's Annual Report on  Form 10‐K for the fiscal year ended December 31, 2021, available from EOG at P.O. Box 4362, Houston, Texas 77210‐4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1‐800‐SEC‐0330 or from the SEC's website at www.sec.gov. In addition, reconciliation schedules and definitions for non‐GAAP financial measures can be found on the EOG website at www.eogresources.com.

Income Statements

In millions of USD, except share data (in millions) and per share data (Unaudited)
	2Q 2022		1Q 2022		2Q 2021		YTD 2022		YTD 2021
Operating Revenues and Other
Crude Oil and Condensate	4,699		3,889		2,699		8,588		4,950
Natural Gas Liquids	777		681		367		1,458		681
Natural Gas	1,000		716		404		1,716		1,029
Losses on Mark-to-Market Financial      Commodity Derivative Contracts	(1,377)		(2,820)		(427)		(4,197)		(794)
Gathering, Processing and Marketing	2,169		1,469		1,022		3,638		1,870
Gains on Asset Dispositions, Net	97		25		51		122		45
Other, Net	42		23		23		65		52
Total	7,407		3,983		4,139		11,390		7,833
Operating Expenses
Lease and Well	324		318		270		642		540
Transportation Costs	244		228		214		472		416
Gathering and Processing Costs	152		144		128		296		267
Exploration Costs	35		45		35		80		68
Dry Hole Costs	20		3		13		23		24
Impairments	91		55		44		146		88
Marketing Costs	2,127		1,283		991		3,410		1,829
Depreciation, Depletion and Amortization	911		847		914		1,758		1,814
General and Administrative	128		124		120		252		230
Taxes Other Than Income	472		390		239		862		454
Total	4,504		3,437		2,968		7,941		5,730
Operating Income	2,903		546		1,171		3,449		2,103
Other Income (Expense), Net	27		(1)		(2)		26		(6)
Income Before Interest Expense and Income      Taxes	2,930		545		1,169		3,475		2,097
Interest Expense, Net	48		48		45		96		92
Income Before Income Taxes	2,882		497		1,124		3,379		2,005
Income Tax Provision	644		107		217		751		421
Net Income	2,238		390		907		2,628		1,584
Dividends Declared per Common Share	2.5500		1.7500		1.4125		4.3000		1.8250
Net Income Per Share
Basic	3.84		0.67		1.56		4.52		2.73
Diluted	3.81		0.67		1.55		4.48		2.72
Average Number of Common Shares
Basic	583		582		580		582		580
Diluted	588		586		584		587		583

Wellhead Volumes and Prices

(Unaudited)
	2Q 2022		2Q 2021		% Change		1Q 2022		YTD 2022		YTD 2021		% Change
Crude Oil and Condensate Volumes      (MBbld) (A)
United States	463.5		446.9		4 %		449.4		456.5		437.8		4 %
Trinidad	0.6		1.7		-65 %		0.7		0.7		2.0		-65 %
Other International (B)	—		—				—		—		—
Total	464.1		448.6		3 %		450.1		457.2		439.8		4 %
Average Crude Oil and Condensate Prices      ($/Bbl) (C)
United States	$ 111.26		66.16		68 %		$    96.02		$   103.80		$      62.22		67 %
Trinidad	98.29		56.26		75 %		83.82		90.33		52.57		72 %
Other International (B)	—		55.56		-100 %		—		—		42.36		-100 %
Composite	111.25		66.12		68 %		96.00		103.78		62.18		67 %
			58.02
Natural Gas Liquids Volumes (MBbld) (A)
United States	201.9		138.5		46 %		190.3		196.1		131.5		49 %
Total	201.9		138.5		46 %		190.3		196.1		131.5		49 %
Average Natural Gas Liquids Prices      ($/Bbl) (C)
United States	$  42.28		$  29.15		45 %		$    39.77		$      41.07		$      28.62		43 %
Composite	42.28		29.15		45 %		39.77		41.07		28.62		43 %
Natural Gas Volumes (MMcfd) (A)
United States	1,324		1,199		10 %		1,249		1,287		1,150		12 %
Trinidad	204		233		-12 %		209		206		225		-8 %
Other International (B)	—		13		-100 %		—		—		19		-100 %
Total	1,528		1,445		6 %		1,458		1,493		1,394		7 %
Average Natural Gas Prices ($/Mcf) (C)
United States	$     7.77		$     2.99		160 %		$       5.81		$        6.83		$        4.19		63 %
Trinidad	3.42		3.37		2 %		3.36		3.39		3.37		0 %
Other International (B)	—		5.69		-100 %		—		—		5.67		-100 %
Composite	7.19		3.07		134 %		5.46		6.35		4.08		56 %
Crude Oil Equivalent Volumes (MBoed) (D)
United States	886.1		785.2		13 %		847.8		867.1		761.0		14 %
Trinidad	34.6		40.6		-15 %		35.5		35.0		39.5		-11 %
Other International (B)	—		2.2		-100 %		—		—		3.1		-100 %
Total	920.7		828.0		11 %		883.3		902.1		803.6		12 %
Total MMBoe (D)	83.8		75.3		11 %		79.5		163.3		145.4		12 %

(A)

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

(B)

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

(C)

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 in EOG's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2022).

(D)

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.

Balance Sheets

In millions of USD, except share data (Unaudited)
	June 30,		December 31,
	2022		2021
Current Assets
Cash and Cash Equivalents	3,073		5,209
Accounts Receivable, Net	3,735		2,335
Inventories	739		584
Assets from Price Risk Management Activities	1		—
Other	605		456
Total	8,153		8,584
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	66,098		67,644
Other Property, Plant and Equipment	4,862		4,753
Total Property, Plant and Equipment	70,960		72,397
Less:  Accumulated Depreciation, Depletion and Amortization	(42,113)		(43,971)
Total Property, Plant and Equipment, Net	28,847		28,426
Deferred Income Taxes	12		11
Other Assets	1,127		1,215
Total Assets	38,139		38,236
Current Liabilities
Accounts Payable	2,896		2,242
Accrued Taxes Payable	594		518
Dividends Payable	437		436
Liabilities from Price Risk Management Activities	79		269
Current Portion of Long-Term Debt	1,282		37
Current Portion of Operating Lease Liabilities	216		240
Other	264		300
Total	5,768		4,042
Long-Term Debt	3,809		5,072
Other Liabilities	2,067		2,193
Deferred Income Taxes	4,183		4,749
Commitments and Contingencies
Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 586,391,670 Shares Issued at June 30, 2022 and 585,521,512 Shares Issued at December 31, 2021	206		206
Additional Paid in Capital	6,128		6,087
Accumulated Other Comprehensive Loss	(12)		(12)
Retained Earnings	16,028		15,919
Common Stock Held in Treasury, 344,705 Shares at June 30, 2022 and 257,268 Shares at December 31, 2021	(38)		(20)
Total Stockholders' Equity	22,312		22,180
Total Liabilities and Stockholders' Equity	38,139		38,236

 

Cash Flows Statements

In millions of USD (Unaudited)
	2Q 2022		2Q 2021		1Q 2022		YTD 2022		YTD 2021
Cash Flows from Operating Activities
Reconciliation of Net Income to Net Cash Provided by      Operating Activities:
Net Income	2,238		907		390		2,628		1,584
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	911		914		847		1,758		1,814
Impairments	91		44		55		146		88
Stock-Based Compensation Expenses	30		31		35		65		66
Deferred Income Taxes	(102)		(97)		(465)		(567)		(133)
Gains on Asset Dispositions, Net	(97)		(51)		(25)		(122)		(45)
Other, Net	(16)		6		6		(10)		13
Dry Hole Costs	20		13		3		23		24
Mark-to-Market Financial Commodity Derivative Contracts Total Losses	1,377		427		2,820		4,197		794
Net Cash Payments for Settlements of Financial      Commodity Derivative Contracts	(2,114)		(193)		(296)		(2,410)		(223)
Other, Net	19		—		2		21		1
Changes in Components of Working Capital and Other       Assets and Liabilities
Accounts Receivable	(522)		(186)		(878)		(1,400)		(494)
Inventories	(157)		37		(14)		(171)		101
Accounts Payable	259		11		130		389		183
Accrued Taxes Payable	(536)		(163)		613		77		80
Other Assets	71		(119)		(213)		(142)		(222)
Other Liabilities	433		32		(2,250)		(1,817)		(57)
Changes in Components of Working Capital Associated      with Investing Activities	143		(54)		68		211		(145)
Net Cash Provided by Operating Activities	2,048		1,559		828		2,876		3,429
Investing Cash Flows
Additions to Oil and Gas Properties	(1,349)		(968)		(939)		(2,288)		(1,843)
Additions to Other Property, Plant and Equipment	(75)		(55)		(70)		(145)		(97)
Proceeds from Sales of Assets	110		141		121		231		146
Other Investing Activities	(30)		—		—		(30)		—
Changes in Components of Working Capital Associated      with Investing Activities	(143)		54		(68)		(211)		145
Net Cash Used in Investing Activities	(1,487)		(828)		(956)		(2,443)		(1,649)
Financing Cash Flows
Long-Term Debt Repayments	—		—		—		—		(750)
Dividends Paid	(1,486)		(239)		(1,023)		(2,509)		(458)
Treasury Stock Purchased	(15)		(2)		(43)		(58)		(12)
Proceeds from Stock Options Exercised and Employee      Stock Purchase Plan	13		9		4		17		9
Repayment of Finance Lease Liabilities	(9)		(9)		(10)		(19)		(18)
Net Cash Used in Financing Activities	(1,497)		(241)		(1,072)		(2,569)		(1,229)
Effect of Exchange Rate Changes on Cash	—		2		—		—		—
Increase (Decrease)  in Cash and Cash Equivalents	(936)		492		(1,200)		(2,136)		551
Cash and Cash Equivalents at Beginning of Period	4,009		3,388		5,209		5,209		3,329
Cash and Cash Equivalents at End of Period	3,073		3,880		4,009		3,073		3,880

  Non-GAAP Financial Measures

To supplement the presentation of its financial results prepared in accordance with generally accepted accounting principles in the United States of America (GAAP), EOG's quarterly earnings releases and related conference calls, accompanying investor presentation slides and presentation slides for investor conferences contain certain financial measures that are not prepared or presented in accordance with GAAP.   These non-GAAP financial measures may include, but are not limited to, Adjusted Net Income (Loss), Cash Flow from Operations Before Working Capital, Free Cash Flow, Adjusted EBITDAX, Net Debt and related statistics.

A reconciliation of each of these measures to their most directly comparable GAAP financial measure and related discussion is included in the tables on the following pages and can also be found in the "Reconciliations & Guidance" section of the "Investors" page of the EOG website at www.eogresources.com.

As further discussed in the tables on the following pages, EOG believes these measures may be useful to investors who follow the practice of some industry analysts who make certain adjustments to GAAP measures (for example, to exclude non-recurring items) to facilitate comparisons to others in EOG's industry, and who utilize non-GAAP measures in their calculations of certain statistics (for example, return on capital employed and return on equity) used to evaluate EOG's performance.

EOG believes that the non-GAAP measures presented, when viewed in combination with its financial and operating results prepared in accordance with GAAP, provide a more complete understanding of the factors and trends affecting the company's performance. As is discussed in the tables on the following pages, EOG uses these non-GAAP measures for purposes of (i) comparing EOG's financial and operating performance with the financial and operating performance of other companies in the industry and (ii) analyzing EOG's financial and operating performance across periods.

The non-GAAP measures presented should not be considered in isolation, and should not be considered as a substitute for, or as an alternative to, EOG's reported Net Income (Loss), Long-Term Debt (including Current Portion of Long-Term Debt), Net Cash Provided by Operating Activities and other financial results calculated in accordance with GAAP. The non-GAAP measures presented should be read in conjunction with EOG's consolidated financial statements prepared in accordance with GAAP.

In addition, because not all companies use identical calculations, EOG's presentation of non-GAAP measures may not be comparable to, and may be calculated differently from, similarly titled measures disclosed by other companies, including its peer companies. EOG may also change the calculation of one or more of its non-GAAP measures from time to time – for example, to account for changes in its business and operations or to more closely conform to peer company or industry analysts' practices.

Adjusted Net Income (Loss)

In millions of USD, except share data (in millions) and per share data (Unaudited)
The following tables adjust the reported Net Income (Loss) (GAAP) to reflect actual net cash received from (payments for) settlements of financial commodity derivative contracts by eliminating the unrealized mark-to-market (gains) losses from these transactions, to eliminate the net (gains) losses on asset dispositions, to add back impairment charges related to certain of EOG's assets (which are generally (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets) - see "Revenues, Costs and Margins Per Barrel of Oil Equivalent" below for additional related discussion) and to make certain other adjustments to exclude non-recurring and certain other items as further described below.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match hedge realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.
	2Q 2022
	Before Tax		Income Tax Impact		After Tax		Diluted Earnings per Share
Reported Net Income (GAAP)	2,882		(644)		2,238		3.81
Adjustments:
Losses on Mark-to-Market Financial Commodity Derivative Contracts	1,377		(299)		1,078		1.82
Net Cash Payments for Settlements of Financial Commodity Derivative      Contracts (1)	(2,114)		459		(1,655)		(2.81)
Less: Gains on Asset Dispositions, Net	(97)		21		(76)		(0.13)
Add: Certain Impairments	36		(7)		29		0.05
Adjustments to Net Income	(798)		174		(624)		(1.07)
Adjusted Net Income (Non-GAAP)	2,084		(470)		1,614		2.74
Average Number of Common Shares (Non-GAAP)
Basic							583
Diluted							588

(1)

Consistent with its customary practice, in calculating Adjusted Net Income (Loss) (non-GAAP), EOG subtracts from reported Net Income (Loss)  (GAAP) the total net cash paid for settlements of financial commodity derivative contracts during such period.  For the second quarter of 2022, such amount was $2,114 million, of which $1,328 million was related to the early termination of certain contracts.  See "Financial Commodity Derivative Contracts" below for further discussion.

Adjusted Net Income (Loss)
(Continued)

In millions of USD, except share data (in millions) and per share data (Unaudited)
	1Q 2022
	Before Tax		Income Tax Impact		After Tax		Diluted Earnings per Share
Reported Net Income (GAAP)	497		(107)		390		0.67
Adjustments:
Losses on Mark-to-Market Financial Commodity Derivative Contracts	2,820		(612)		2,208		3.76
Net Cash Payments for Settlements of Financial Commodity Derivative       Contracts	(296)		64		(232)		(0.40)
Less: Gains on Asset Dispositions, Net	(25)		5		(20)		(0.03)
Adjustments to Net Income	2,499		(543)		1,956		3.33
Adjusted Net Income (Non-GAAP)	2,996		(650)		2,346		4.00
Average Number of Common Shares (Non-GAAP)
Basic							582
Diluted							586

 

	2Q 2021
	Before Tax		Income Tax Impact		After Tax		Diluted Earnings per Share
Reported Net Income (GAAP)	1,124		(217)		907		1.55
Adjustments:
Losses on Mark-to-Market Financial Commodity Derivative Contracts	427		(93)		334		0.58
Net Cash Payments for Settlements of Financial Commodity Derivative      Contracts	(193)		42		(151)		(0.26)
Less: Gains on Asset Dispositions, Net	(51)		17		(34)		(0.06)
Add: Certain Impairments	1		—		1		—
Less: Tax Benefits Related to Exiting Canada Operations	—		(45)		(45)		(0.08)
Adjustments to Net Income	184		(79)		105		0.18
Adjusted Net Income (Non-GAAP)	1,308		(296)		1,012		1.73
Average Number of Common Shares (Non-GAAP)
Basic							580
Diluted							584

 

	YTD 2022
	Before Tax		Income Tax Impact		After Tax		Diluted Earnings per Share
Reported Net Income (GAAP)	3,379		(751)		2,628		4.48
Adjustments:
Losses on Mark-to-Market Commodity Derivative Contracts	4,197		(911)		3,286		5.59
Net Cash Payments for Settlements of Financial Commodity      Derivative Contracts (1)	(2,410)		523		(1,887)		(3.21)
Less: Gains on Asset Dispositions, Net	(122)		26		(96)		(0.16)
Add: Certain Impairments	36		(7)		29		0.05
Adjustments to Net Income	1,701		(369)		1,332		2.27
Adjusted Net Income (Non-GAAP)	5,080		(1,120)		3,960		6.75
Average Number of Common Shares (Non-GAAP)
Basic							582
Diluted							587

(1)

Consistent with its customary practice, in calculating Adjusted Net Income (Loss) (non-GAAP), EOG subtracts from reported Net Income (Loss) (GAAP) the total net cash paid for settlements of financial commodity derivative contracts during such period.  For the first six months of 2022, such amount was $2,410 million, of which $1,328 million was related to the early termination of certain contracts.  See "Financial Commodity Derivative Contracts" below for further discussion.

 

	YTD 2021
	Before Tax		Income Tax Impact		After Tax		Diluted Earnings per Share
Reported Net Income (GAAP)	2,005		(421)		1,584		2.72
Adjustments:
Losses on Mark-to-Market Commodity Derivative Contracts	794		(174)		620		1.07
Net Cash Payments from Settlements of Commodity Derivative Contracts	(223)		49		(174)		(0.30)
Less: Gains on Asset Dispositions, Net	(45)		16		(29)		(0.05)
Add: Certain Impairments	2		—		2		—
Less: Tax Benefits Related to Exiting Canada Operations	—		(45)		(45)		(0.08)
Adjustments to Net Income	528		(154)		374		0.64
Adjusted Net Income (Non-GAAP)	2,533		(575)		1,958		3.36
Average Number of Common Shares (Non-GAAP)
Basic							580
Diluted							583

 

Adjusted Net Income Per Share 

In millions of USD, except share data (in millions), per share data, production volume data and per Boe data (Unaudited)
1Q 2022 Adjusted Net Income per Share (Non-GAAP)			4.00
Realized Price
2Q 2022 Composite Average Wellhead Revenue per Boe	77.29
Less:  1Q 2022 Composite Average Welhead Revenue per Boe	(66.50)
Subtotal	10.79
Multiplied by: 2Q 2022 Crude Oil Equivalent Volumes (MMBoe)	83.8
Total Change in Revenue	904
Less: Income Tax Benefit (Provision) Imputed (based on 23%)	(208)
Change in Net Income	696
Change in Diluted Earnings per Share			1.18
Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts
2Q 2022 Net Cash Received from (Payments for) Settlement of Financial      Commodity Derivative Contracts	(2,114)
Less:  Income Tax Benefit (Provision)	459
After Tax - (a)	(1,655)
1Q 2022 Net Cash Received from (Payments for) Settlement of Financial      Commodity Derivative Contracts	(296)
Less:  Income Tax Benefit (Provision)	64
After Tax - (b)	(232)
Change in Net Income - (a) - (b)	(1,423)
Change in Diluted Earnings per Share			(2.42)
Wellhead Volumes
2Q 2022 Crude Oil Equivalent Volumes (MMBoe)	83.8
Less:  1Q 2022 Crude Oil Equivalent Volumes (MMBoe)	(79.5)
Subtotal	4.3
Multiplied by:  2Q 2022 Composite Average Margin per Boe (Non-GAAP) (Including      Total Exploration Costs) (refer to "Revenues, Costs and Margins Per Barrel of Oil      Equivalent" schedule)	48.79
Change in Revenue	209
Less:  Income Tax Benefit (Provision) Imputed (based on 23%)	(48)
Change in Net Income	161
Change in Diluted Earnings per Share			0.27
Operating Cost per Boe
1Q 2022 Total Operating Cost per Boe (Non-GAAP) (including Total Exploration      Costs) (refer to "Revenues, Costs and Margins Per Barrel of Oil Equivalent"      schedule)	27.70
Less:  1Q 2022 Taxes Other Than Income	(4.91)
Less:  2Q 2022 Total Operating Cost per Boe (Non-GAAP) (including Total      Exploration Costs) (refer to "Revenues, Costs and Margins Per Barrel of Oil      Equivalent" schedule)	(28.50)
Add: 2Q 2022 Taxes Other Than Income	5.63
Subtotal	(0.08)
Multiplied by:  2Q 2022 Crude Oil Equivalent Volumes (MMBoe)	83.8
Change in Before-Tax Net Income	(7)
Less:  Income Tax Benefit (Provision) Imputed (based on 23%)	2
Change in Net Income	(5)
Change in Diluted Earnings per Share			(0.01)
Other (1)			(0.28)
2Q 2022 Adjusted Net Income per Share (Non-GAAP)			2.74
2Q 2022 Average Number of Common Shares (Non-GAAP) - Diluted	588

(1)	Includes gathering, processing and marketing revenue, other revenue, marketing costs, taxes other than income, other income (expense), interest expense and the effect of changes in the effective income tax rate.

 

Cash Flow from Operations and Free Cash Flow 

In millions of USD (Unaudited)
The following tables reconcile Net Cash Provided by Operating Activities (GAAP) to Cash Flow from Operations Before Working Capital (Non-GAAP). EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust Net Cash Provided by Operating Activities for Changes in Components of Working Capital and Other Assets and Liabilities, Changes in Components of Working Capital Associated with Investing and Financing Activities and certain other adjustments to exclude non-recurring and certain other items as further described below. EOG defines Free Cash Flow (Non-GAAP) for a given period as Cash Flow from Operations Before Working Capital (Non-GAAP) (see below reconciliation) for such period less the total capital expenditures (Non-GAAP) during such period, as is illustrated below. EOG management uses this information for comparative purposes within the industry.  To further the comparability of EOG's financial results with those of EOG's peer companies and other companies in the industry, EOG now utilizes Cash Flow from Operations Before Working Capital (Non-GAAP), instead of Discretionary Cash Flow (Non-GAAP), in calculating its Free Cash Flow (Non-GAAP).  Accordingly, Free Cash Flow (Non-GAAP) for the three-month and six-month periods ended June 30, 2022 have been calculated on such basis, and the calculations of Free Cash Flow (Non-GAAP) for each of the prior periods shown have been revised and conformed.
	2Q 2022		1Q 2022		4Q 2021		3Q 2021		2Q 2021
Net Cash Provided by Operating Activities (GAAP)	2,048		828		3,166		2,196		1,559
Adjustments:
Changes in Components of Working Capital and      Other Assets and Liabilities
Accounts Receivable	522		878		182		145		186
Inventories	157		14		108		6		(37)
Accounts Payable	(259)		(130)		(341)		68		(11)
Accrued Taxes Payable	536		(613)		(26)		(206)		163
Other Assets	(71)		213		81		(167)		119
Other Liabilities	(433)		2,250		(201)		260		(32)
Changes in Components of Working Capital      Associated with Investing Activities	(143)		(68)		100		(45)		54
Cash Flow from Operations Before Working Capital      (Non-GAAP)	2,357		3,372		3,069		2,257		2,001
Cash Flow from Operations Before Working Capital      (Non-GAAP)	2,357		3,372		3,069		2,257		2,001
Less:
Total Capital Expenditures (Non-GAAP) (a)	(1,071)		(1,009)		(1,015)		(891)		(937)
Free Cash Flow (Non-GAAP)	1,286		2,363		2,054		1,366		1,064
(a) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP):
	2Q 2022		1Q 2022		4Q 2021		3Q 2021		2Q 2021
Total Expenditures (GAAP)	1,521		1,144		1,137		962		1,089
Less:
Asset Retirement Costs	(43)		(27)		(71)		(8)		(31)
Non-Cash Acquisition Costs of Unproved      Properties	(21)		(58)		(8)		(15)		—
Non-Cash Finance Leases	—		—		—		—		—
Acquisition Costs of Proved Properties	(351)		(5)		(1)		(4)		(86)
Exploration Costs	(35)		(45)		(42)		(44)		(35)
Total Capital Expenditures (Non-GAAP)	1,071		1,009		1,015		891		937

Cash Flow from Operations and Free Cash Flow
(Continued)

In millions of USD (Unaudited)
							YTD 2022		YTD 2021
Net Cash Provided by Operating Activities (GAAP)							2,876		3,429
Adjustments:
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable							1,400		494
Inventories							171		(101)
Accounts Payable							(389)		(183)
Accrued Taxes Payable							(77)		(80)
Other Assets							142		222
Other Liabilities							1,817		57
Changes in Components of Working Capital Associated with Investing Activities							(211)		145
Cash Flow from Operations Before Working Capital (Non-GAAP)							5,729		3,983
Cash Flow from Operations Before Working Capital (Non-GAAP)							5,729		3,983
Less:
Total Capital Expenditures (Non-GAAP) (a)							(2,080)		(1,849)
Free Cash Flow (Non-GAAP)							3,649		2,134
(a) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP):
							YTD 2022		YTD 2021
Total Expenditures (GAAP)							2,665		2,156
Less:
Asset Retirement Costs							(70)		(48)
Non-Cash Acquisition Costs of Unproved Properties							(79)		(22)
Non-Cash Finance Leases							—		(74)
Acquisition Costs of Proved Properties							(356)		(95)
Exploration Costs							(80)		(68)
Total Capital Expenditures (Non-GAAP)							2,080		1,849

Cash Flow from Operations and Free Cash Flow
(Continued)

In millions of USD (Unaudited)
	FY 2021		FY 2020		FY 2019
Net Cash Provided by Operating Activities (GAAP)	8,791		5,008		8,163
Adjustments:
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	821		(467)		92
Inventories	13		(123)		(90)
Accounts Payable	(456)		795		(169)
Accrued Taxes Payable	(312)		49		(40)
Other Assets	136		(325)		(358)
Other Liabilities	116		(8)		57
Changes in Components of Working Capital Associated with Investing and Financing       Activities	200		(75)		115
Other Non-Current Income Taxes - Net Receivable	—		113		239
Cash Flow from Operations Before Working Capital (Non-GAAP)	9,309		4,967		8,009
Cash Flow from Operations Before Working Capital (Non-GAAP)	9,309		4,967		8,009
Less:
Total Capital Expenditures (Non-GAAP) (a)	(3,755)		(3,344)		(6,094)
Free Cash Flow (Non-GAAP)	5,554		1,623		1,915
(a) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP):
Total Expenditures (GAAP)	4,255		4,113		6,900
Less:
Asset Retirement Costs	(127)		(117)		(186)
Non-Cash Expenditures of Other Property, Plant and Equipment	—		—		(2)
Non-Cash Acquisition Costs of Unproved Properties	(45)		(197)		(98)
Non-Cash Finance Leases	(74)		(174)		—
Acquisition Costs of Proved Properties	(100)		(135)		(380)
Exploration Costs	(154)		(146)		(140)
Total Capital Expenditures (Non-GAAP)	3,755		3,344		6,094

Cash Flow from Operations and Free Cash Flow
(Continued)

In millions of USD (Unaudited)
	FY 2018		FY 2017		FY 2016
Net Cash Provided by Operating Activities (GAAP)	7,769		4,265		2,359
Adjustments:
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	368		392		233
Inventories	395		175		(171)
Accounts Payable	(439)		(324)		74
Accrued Taxes Payable	92		64		(93)
Other Assets	125		659		41
Other Liabilities	(11)		90		16
Changes in Components of Working Capital Associated with Investing and Financing      Activities	(301)		(90)		156
Other Non-Current Income Taxes - Net (Payable) Receivable	149		(513)		—
Excess Tax Benefits from Stock-Based Compensation	—		—		30
Cash Flow from Operations Before Working Capital (Non-GAAP)	8,147		4,718		2,645
Cash Flow from Operations Before Working Capital (Non-GAAP)	8,147		4,718		2,645
Less:
Total Capital Expenditures (Non-GAAP) (a)	(6,023)		(4,083)		(2,581)
Free Cash Flow (Non-GAAP)	2,124		635		64
(a) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP):
Total Expenditures (GAAP)	6,706		4,613		6,554
Less:
Asset Retirement Costs	(70)		(56)		20
Non-Cash Expenditures of Other Property, Plant and Equipment	(1)		—		(17)
Non-Cash Acquisition Costs of Unproved Properties	(291)		(256)		(3,102)
Non-Cash Finance Leases	(48)		—		—
Acquisition Costs of Proved Properties	(124)		(73)		(749)
Exploration Costs	(149)		(145)		(125)
Total Capital Expenditures (Non-GAAP)	6,023		4,083		2,581

Total Expenditures

In millions of USD (Unaudited)
	2Q 2022		1Q 2022		4Q 2021		3Q 2021		2Q 2021		YTD 2022		YTD 2021
Exploration and Development Drilling	866		813		767		653		711		1,679		1,444
Facilities	90		109		118		100		105		199		187
Leasehold Acquisitions	34		64		21		90		46		98		104
Property Acquisitions	351		5		1		4		86		356		95
Capitalized Interest	7		8		9		9		7		15		15
Subtotal	1,348		999		916		856		955		2,347		1,845
Exploration Costs	35		45		42		44		35		80		68
Dry Hole Costs	20		3		43		4		13		23		24
Exploration and Development      Expenditures	1,403		1,047		1,001		904		1,003		2,450		1,937
Asset Retirement Costs	43		27		71		8		31		70		48
Total Exploration and Development      Expenditures	1,446		1,074		1,072		912		1,034		2,520		1,985
Other Property, Plant and Equipment	75		70		65		50		55		145		171
Total Expenditures	1,521		1,144		1,137		962		1,089		2,665		2,156

Total Expenditures
(Continued)

In millions of USD (Unaudited)
	FY 2021		FY 2020		FY 2019		FY 2018		FY 2017		FY 2016
Exploration and Development Drilling	2,864		2,664		4,951		4,935		3,132		1,957
Facilities	405		347		629		625		575		375
Leasehold Acquisitions	215		265		276		488		427		3,217
Property Acquisitions	100		135		380		124		73		749
Capitalized Interest	33		31		38		24		27		31
Subtotal	3,617		3,442		6,274		6,196		4,234		6,329
Exploration Costs	154		146		140		149		145		125
Dry Hole Costs	71		13		28		5		5		11
Exploration and Development Expenditures	3,842		3,601		6,442		6,350		4,384		6,465
Asset Retirement Costs	127		117		186		70		56		(20)
Total Exploration and Development Expenditures	3,969		3,718		6,628		6,420		4,440		6,445
Other Property, Plant and Equipment	286		395		272		286		173		109
Total Expenditures	4,255		4,113		6,900		6,706		4,613		6,554

 

EBITDAX and Adjusted EBITDAX

In millions of USD (Unaudited)
The following table adjusts the reported Net Income (Loss) (GAAP) to Earnings Before Interest Expense, Net, Income Taxes (Income Tax Provision (Benefit)), Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments (EBITDAX) (Non-GAAP) and further adjusts such amount to reflect actual Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts by eliminating the unrealized Mark-to-Market (MTM) (Gains) Losses from these transactions and to eliminate the (Gains) Losses on Asset Dispositions (Net).  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported Net Income (Loss) (GAAP) to add back Interest Expense, Net, Income Taxes (Income Tax Provision (Benefit)), Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments and further adjust such amount to match realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.
	2Q 2022	2Q 2021	YTD 2022	YTD 2021
Net Income (GAAP)	2,238	907	2,628	1,584
Adjustments:
Interest Expense, Net	48	45	96	92
Income Tax Provision	644	217	751	421
Depreciation, Depletion and Amortization	911	914	1,758	1,814
Exploration Costs	35	35	80	68
Dry Hole Costs	20	13	23	24
Impairments	91	44	146	88
EBITDAX (Non-GAAP)	3,987	2,175	5,482	4,091
Losses on MTM Financial Commodity Derivative Contracts	1,377	427	4,197	794
Net Cash Payments for Settlements of Commodity Derivative Contracts	(2,114)	(193)	(2,410)	(223)
Gains on Asset Dispositions, Net	(97)	(51)	(122)	(45)
Adjusted EBITDAX (Non-GAAP)	3,153	2,358	7,147	4,617
Definitions
EBITDAX - Earnings Before Interest Expense, Net; Income Tax Provision (Benefit); Depreciation, Depletion and Amortization; Exploration Costs; Dry Hole Costs; and Impairments

 Net Debt-to-Total Capitalization Ratio

In millions of USD, except ratio data (Unaudited)
The following tables reconcile Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation.  A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation.  EOG management uses this information for comparative purposes within the industry.
	June 30, 2022		March 31, 2022
Total Stockholders' Equity - (a)	22,312		21,540
Current and Long-Term Debt (GAAP) - (b)	5,091		5,099
Less: Cash	(3,073)		(4,009)
Net Debt (Non-GAAP) - (c)	2,018		1,090
Total Capitalization (GAAP) - (a) + (b)	27,403		26,639
Total Capitalization (Non-GAAP) - (a) + (c)	24,330		22,630
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	18.6 %		19.1 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	8.3 %		4.8 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2021		September 30, 2021		June 30, 2021		March 31, 2021
Total Stockholders' Equity - (a)	22,180		21,765		20,881		20,762
Current and Long-Term Debt (GAAP) - (b)	5,109		5,117		5,125		5,133
Less: Cash	(5,209)		(4,293)		(3,880)		(3,388)
Net Debt (Non-GAAP) - (c)	(100)		824		1,245		1,745
Total Capitalization (GAAP) - (a) + (b)	27,289		26,882		26,006		25,895
Total Capitalization (Non-GAAP) - (a) + (c)	22,080		22,589		22,126		22,507
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	18.7 %		19.0 %		19.7 %		19.8 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	-0.5 %		3.6 %		5.6 %		7.8 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2020		September 30, 2020		June 30, 2020		March 31, 2020
Total Stockholders' Equity - (a)	20,302		20,148		20,388		21,471
Current and Long-Term Debt (GAAP) - (b)	5,816		5,721		5,724		5,222
Less: Cash	(3,329)		(3,066)		(2,417)		(2,907)
Net Debt (Non-GAAP) - (c)	2,487		2,655		3,307		2,315
Total Capitalization (GAAP) - (a) + (b)	26,118		25,869		26,112		26,693
Total Capitalization (Non-GAAP) - (a) + (c)	22,789		22,803		23,695		23,786
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	22.3 %		22.1 %		21.9 %		19.6 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	10.9 %		11.6 %		14.0 %		9.7 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2019		September 30, 2019		June 30, 2019		March 31, 2019
Total Stockholders' Equity - (a)	21,641		21,124		20,630		19,904
Current and Long-Term Debt (GAAP) - (b)	5,175		5,177		5,179		6,081
Less: Cash	(2,028)		(1,583)		(1,160)		(1,136)
Net Debt (Non-GAAP) - (c)	3,147		3,594		4,019		4,945
Total Capitalization (GAAP) - (a) + (b)	26,816		26,301		25,809		25,985
Total Capitalization (Non-GAAP) - (a) + (c)	24,788		24,718		24,649		24,849
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	19.3 %		19.7 %		20.1 %		23.4 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	12.7 %		14.5 %		16.3 %		19.9 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2018		September 30, 2018		June 30, 2018		March 31, 2018
Total Stockholders' Equity - (a)	19,364		18,538		17,452		16,841
Current and Long-Term Debt (GAAP) - (b)	6,083		6,435		6,435		6,435
Less: Cash	(1,556)		(1,274)		(1,008)		(816)
Net Debt (Non-GAAP) - (c)	4,527		5,161		5,427		5,619
Total Capitalization (GAAP) - (a) + (b)	25,447		24,973		23,887		23,276
Total Capitalization (Non-GAAP) - (a) + (c)	23,891		23,699		22,879		22,460
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	23.9 %		25.8 %		26.9 %		27.6 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	18.9 %		21.8 %		23.7 %		25.0 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2017		September 30, 2017		June 30, 2017		March 31, 2017
Total Stockholders' Equity - (a)	16,283		13,922		13,902		13,928
Current and Long-Term Debt (GAAP) - (b)	6,387		6,387		6,987		6,987
Less: Cash	(834)		(846)		(1,649)		(1,547)
Net Debt (Non-GAAP) - (c)	5,553		5,541		5,338		5,440
Total Capitalization (GAAP) - (a) + (b)	22,670		20,309		20,889		20,915
Total Capitalization (Non-GAAP) - (a) + (c)	21,836		19,463		19,240		19,368
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	28.2 %		31.4 %		33.4 %		33.4 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	25.4 %		28.5 %		27.7 %		28.1 %

Net Debt-to-Total Capitalization Ratio
(Continued)

In millions of USD, except ratio data (Unaudited)
	December 31, 2016		September 30, 2016		June 30, 2016		March 31, 2016		December 31, 2015
Total Stockholders' Equity - (a)	13,982		11,798		12,057		12,405		12,943
Current and Long-Term Debt (GAAP) - (b)	6,986		6,986		6,986		6,986		6,656
Less: Cash	(1,600)		(1,049)		(780)		(668)		(719)
Net Debt (Non-GAAP) - (c)	5,386		5,937		6,206		6,318		5,937
Total Capitalization (GAAP) - (a) + (b)	20,968		18,784		19,043		19,391		19,599
Total Capitalization (Non-GAAP) - (a) + (c)	19,368		17,735		18,263		18,723		18,880
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]	33.3 %		37.2 %		36.7 %		36.0 %		34.0 %
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]	27.8 %		33.5 %		34.0 %		33.7 %		31.4 %

 

Reserve Replacement Cost Data

	In millions of USD, except reserves and ratio data (Unaudited)
	The following table reconciles Total Costs Incurred in Exploration and Development Activities (GAAP) to Total Exploration and Development Expenditures for Drilling Only (Non-GAAP) and Total Exploration and Development Expenditures (Non-GAAP), as used in the calculation of Reserve Replacement Costs per Boe.  There are numerous ways that industry participants present Reserve Replacement Costs, including "Drilling Only" and "All-In", which reflect total exploration and development expenditures divided by total net proved reserve additions from extensions and discoveries only, or from all sources.  Combined with Reserve Replacement, these statistics (and the non-GAAP measures used in calculating such statistics) provide management and investors with an indication of the results of the current year capital investment program.  Reserve Replacement Cost statistics (and the non-GAAP measures used in calculating such statistics) are widely recognized and reported by industry participants and are used by EOG management and other third parties for comparative purposes within the industry.  Please note that the actual cost of adding reserves will vary from the reported statistics due to timing differences in reserve bookings and capital expenditures.  Accordingly, some analysts use three or five year averages of reported statistics, while others prefer to estimate future costs.  EOG has not included future capital costs to develop proved undeveloped reserves in exploration and development expenditures.
			2021				2020				2019				2018
	Total Costs Incurred in Exploration and Development Activities (GAAP)		3,969				3,718				6,628				6,420
	Less:  Asset Retirement Costs		(127)				(117)				(186)				(70)
	Non-Cash Acquisition Costs of Unproved Properties		(45)				(197)				(98)				(291)
	Acquisition Costs of Proved Properties		(100)				(135)				(380)				(124)
	Total Exploration and Development Expenditures for Drilling Only (Non- GAAP) - (a)		3,697				3,269				5,964				5,935
	Total Costs Incurred in Exploration and Development Activities (GAAP)		3,969				3,718				6,628				6,420
	Less:  Asset Retirement Costs		(127)				(117)				(186)				(70)
	Non-Cash Acquisition Costs of Unproved Properties		(45)				(197)				(98)				(291)
	Non-Cash Acquisition Costs of Proved Properties		(5)				(15)				(52)				(71)
	Total Exploration and Development Expenditures (Non-GAAP) - (b)		3,792				3,389				6,292				5,988
	Net Proved Reserve Additions From All Sources - Oil Equivalents (MMBoe)
	Revisions Due to Price - (c)		194				(278)				(60)				35
	Revisions Other Than Price		(308)				(89)				—				(40)
	Purchases in Place		9				10				17				12
	Extensions, Discoveries and Other Additions - (d)		952				564				750				670
	Total Proved Reserve Additions - (e)		847				207				707				677
	Sales in Place		(11)				(31)				(5)				(11)
	Net Proved Reserve Additions From All Sources		836				176				702				666
	Production		309				285				301				265
	Reserve Replacement Costs ($ / Boe)
	Total Drilling, Before Revisions - (a / d)		3.88				5.79				7.95				8.86
	All-in Total, Net of Revisions - (b / e)		4.48				16.32				8.90				8.85
	All-in Total, Excluding Revisions Due to Price -  (b / ( e - c))		5.81				6.98				8.21				9.33

Reserve Replacement Cost Data
(Continued)

In millions of USD, except reserves and ratio data (Unaudited)
		2017				2016				2015				2014
Total Costs Incurred in Exploration and Development Activities (GAAP)		4,440				6,445				4,928				7,905
Less:  Asset Retirement Costs		(56)				20				(53)				(196)
Non-Cash Acquisition Costs of Unproved Properties		(256)				(3,102)				—				—
Acquisition Costs of Proved Properties		(73)				(749)				(481)				(139)
Total Exploration and Development Expenditures for Drilling Only (Non- GAAP) - (a)		4,055				2,614				4,394				7,570
Total Costs Incurred in Exploration and Development Activities (GAAP)		4,440				6,445				4,928				7,905
Less:  Asset Retirement Costs		(56)				20				(53)				(196)
Non-Cash Acquisition Costs of Unproved Properties		(256)				(3,102)				—				—
Non-Cash Acquisition Costs of Proved Properties		(26)				(732)				—				—
Total Exploration and Development Expenditures (Non-GAAP) - (b)		4,102				2,631				4,875				7,709
Net Proved Reserve Additions From All Sources - Oil Equivalents (MMBoe)
Revisions Due to Price - (c)		154				(101)				(574)				52
Revisions Other Than Price		48				253				107				49
Purchases in Place		2				42				56				14
Extensions, Discoveries and Other Additions - (d)		421				209				246				519
Total Proved Reserve Additions - (e)		625				403				(165)				634
Sales in Place		(21)				(168)				(4)				(36)
Net Proved Reserve Additions From All Sources		604				235				(169)				598
Production		224				206				210				220
Reserve Replacement Costs ($ / Boe)
Total Drilling, Before Revisions - (a / d)		9.64				12.51				17.87				14.58
All-in Total, Net of Revisions - (b / e)		6.56				6.52				(29.63)				12.16
All-in Total, Excluding Revisions Due to Price -  (b / ( e - c))		8.71				5.22				11.91				13.25

Definitions
$/Boe	U.S. Dollars per barrel of oil equivalent
MMBoe	Million barrels of oil equivalent

 

Financial Commodity Derivative Contracts

EOG accounts for financial commodity derivative contracts using the mark-to-market accounting method.

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

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 WTI		140		$             65.58		—		$                   —
April  - June 2022 (closed)		NYMEX WTI		140		65.62		—		—
July 2022 (closed)		NYMEX WTI		140		65.59		—		—
August - September 2022		NYMEX WTI		140		65.59		—		—
October - December 2022 (closed) (1)		NYMEX WTI		53		66.11		—		—
October - December 2022		NYMEX WTI		87		65.41		87		88.85
January - February 2023 (closed) (1)		NYMEX WTI		7		69.51		—		—
January - February 2023		NYMEX WTI		143		67.84		6		102.26
March 2023 (closed) (1)		NYMEX WTI		37		67.35		—		—
March 2023		NYMEX WTI		113		68.11		6		102.26
April - May 2023 (closed) (1)		NYMEX WTI		29		68.28		—		—
April - May 2023		NYMEX WTI		91		67.63		2		98.15
June 2023 (closed) (1)		NYMEX WTI		118		67.77		—		—
June 2023		NYMEX WTI		2		69.10		2		98.15
July - September 2023 (closed) (1)		NYMEX WTI		100		70.15		—		—
October - December 2023 (closed) (1)		NYMEX WTI		69		69.41		—		—

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

Financial Commodity Derivative Contracts
(Continued)

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

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

 Natural Gas Financial Price Swap Contracts

				Contracts Sold
Period		Settlement Index		Volume (MMBtud in thousands)		Weighted Average Price ($/MMBtu)
January - August 2022 (closed)		NYMEX Henry Hub		725		$                                    3.57
September 2022		NYMEX Henry Hub		725		3.57
October - December 2022 (closed) (1)		NYMEX Henry Hub		425		3.05
October - December 2022		NYMEX Henry Hub		300		4.32
January - December 2023 (closed) (1)		NYMEX Henry Hub		425		3.05
January - December 2023		NYMEX Henry Hub		300		3.36
January - December 2024		NYMEX Henry Hub		725		3.07
January - December 2025		NYMEX Henry Hub		725		3.07

(1)	In the second quarter of 2022, EOG executed the early termination provision granting EOG the right to terminate certain of its October 2022 - December 2023 natural gas  financial price swap contracts which were open at that time.  EOG paid net cash of $735 million for the settlement of these contracts.

 Natural Gas Basis Swap Contracts

				Contracts Sold
Period		Settlement Index		Volume (MMBtud in thousands)		Weighted Average Price Differential ($/MMBtu)
January - July 2022 (closed)		NYMEX Henry Hub HSC Differential (1)		210		$                                   (0.01)
August - December 2022		NYMEX Henry Hub HSC Differential (1)		210		(0.01)
January - December 2023		NYMEX Henry Hub HSC Differential (1)		135		(0.01)
January - 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.

 

Glossary:
$/Bbl	Dollars per barrel
$/MMBtu	Dollars per million British Thermal Units
Bbl	Barrel
EOG	EOG Resources, Inc.
HSC	Houston Ship Channel
MBbld	Thousand barrels per day
MMBtu	Million British Thermal Units
MMBtud	Million British Thermal Units per day
NGL	Natural Gas Liquids
NYMEX	New York Mercantile Exchange
WTI	West Texas Intermediate

Direct After-Tax Rate of Return

The calculation of EOG's direct after-tax rate of return (ATROR) with respect to EOG's capital expenditure program for a particular play or well is based on the estimated recoverable reserves ("net" to EOG's interest) for all wells in such play or such well (as the case may be), the estimated net present value (NPV) of the future net cash flows from such reserves (for which we utilize certain assumptions regarding future commodity prices and operating costs) and EOG's direct net costs incurred in drilling or acquiring (as the case may be) such wells or well (as the case may be).  As such, EOG's direct ATROR with respect to our capital expenditures for a particular play or well cannot be calculated from our consolidated financial statements.
Direct ATROR
Based on Cash Flow and Time Value of Money
- Estimated future commodity prices and operating costs
- Costs incurred to drill, complete and equip a well, including wellsite  facilities and flowback
Excludes Indirect Capital
- Gathering and Processing and other Midstream
- Land, Seismic, Geological and Geophysical
- Offsite Production Facilities
Payback ~12 Months on 100% Direct ATROR Wells
First Five Years ~1/2 Estimated Ultimate Recovery Produced but ~3/4 of NPV Captured
Return on Equity / Return on Capital Employed
Based on GAAP Accrual Accounting
Includes All Indirect Capital and Growth Capital for Infrastructure
- Eagle Ford, Bakken, Permian, Powder River Basin and Dorado Facilities
- Gathering and Processing
Includes Legacy Gas Capital and Capital from Mature Wells

ROCE & ROE

In millions of USD, except ratio data (Unaudited)
The following tables reconcile Interest Expense, Net (GAAP), Net Income (Loss) (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Adjusted Net Income (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) and Return on Equity (ROE) calculations.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Adjusted Net Income, Net Debt and Total Capitalization (Non-GAAP) in their ROCE and ROE calculations.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.
	2021		2020		2019		2018
Interest Expense, Net (GAAP)	178		205		185		245
Tax Benefit Imputed (based on 21%)	(37)		(43)		(39)		(51)
After-Tax Net Interest Expense (Non-GAAP) - (a)	141		162		146		194
Net Income (Loss) (GAAP) - (b)	4,664		(605)		2,735		3,419
Adjustments to Net Income (Loss), Net of Tax (See Below Detail) (1)	364		1,455		158		(201)
Adjusted Net Income (Non-GAAP) - (c)	5,028		850		2,893		3,218
Total Stockholders' Equity - (d)	22,180		20,302		21,641		19,364
Average Total Stockholders' Equity * - (e)	21,241		20,972		20,503		17,824
Current and Long-Term Debt (GAAP) - (f)	5,109		5,816		5,175		6,083
Less:  Cash	(5,209)		(3,329)		(2,028)		(1,556)
Net Debt (Non-GAAP) - (g)	(100)		2,487		3,147		4,527
Total Capitalization (GAAP) - (d) + (f)	27,289		26,118		26,816		25,447
Total Capitalization (Non-GAAP) - (d) + (g)	22,080		22,789		24,788		23,891
Average Total Capitalization (Non-GAAP) * - (h)	22,435		23,789		24,340		22,864
Return on Capital Employed (ROCE)
Calculated Using GAAP Net Income (Loss) - [(a) + (b)] / (h) (Non-      GAAP)	21.4 %		-1.9 %		11.8 %		15.8 %
Calculated Using Non-GAAP Adjusted Net Income - [(a) + (c)] / (h)      (Non-GAAP)	23.0 %		4.3 %		12.5 %		14.9 %
Return on Equity (ROE)
Calculated Using GAAP Net Income (Loss) - (b) / (e) (GAAP)	22.0 %		-2.9 %		13.3 %		19.2 %
Calculated Using Non-GAAP Adjusted Net Income - (c) / (e) (Non-      GAAP)	23.7 %		4.1 %		14.1 %		18.1 %
* Average for the current and immediately preceding year

ROCE & ROE
(Continued)

(1) Detail of adjustments to Net Income (Loss) (GAAP):
			Before Tax		Income Tax Impact		After Tax
Year Ended December 31, 2021
Adjustments:
Add:  Mark-to-Market Financial Commodity Derivative Contracts Impact			514		(112)		402
Add:  Certain Impairments			15		—		15
Less:  Gains on Asset Dispositions, Net			(17)		9		(8)
Less:  Tax Benefits Related to Exiting Canada Operations			—		(45)		(45)
Total			512		(148)		364
Year Ended December 31, 2020
Adjustments:
Add:  Mark-to-Market Financial Commodity Derivative Contracts Impact			(74)		16		(58)
Add:  Certain Impairments			1,868		(392)		1,476
Add:  Losses on Asset Dispositions, Net			47		(10)		37
Total			1,841		(386)		1,455
Year Ended December 31, 2019
Adjustments:
Add:  Mark-to-Market Financial Commodity Derivative Contracts Impact			51		(11)		40
Add:  Certain Impairments			275		(60)		215
Less:  Gains on Asset Dispositions, Net			(124)		27		(97)
Total			202		(44)		158
Year Ended December 31, 2018
Adjustments:
Add:  Mark-to-Market Financial Commodity Derivative Contracts Impact			(93)		20		(73)
Add:  Certain Impairments			153		(34)		119
Less:  Gains on Asset Dispositions, Net			(175)		38		(137)
Less:  Tax Reform Impact			—		(110)		(110)
Total			(115)		(86)		(201)

ROCE & ROE

In millions of USD, except ratio data (Unaudited)
The following tables reconcile Interest Expense, Net (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) and Return on Equity (ROE) calculations.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.
					2017		2016		2015
Interest Expense, Net (GAAP)					274		282		237
Tax Benefit Imputed (based on 35%)					(96)		(99)		(83)
After-Tax Net Interest Expense (Non-GAAP) - (a)					178		183		154
Net Income (Loss) (GAAP) - (b)					2,583		(1,097)		(4,525)
Total Stockholders' Equity - (d)					16,283		13,982		12,943
Average Total Stockholders' Equity* - (e)					15,133		13,463		15,328
Current and Long-Term Debt (GAAP) - (f)					6,387		6,986		6,655
Less:  Cash					(834)		(1,600)		(719)
Net Debt (Non-GAAP) - (g)					5,553		5,386		5,936
Total Capitalization (GAAP) - (d) + (f)					22,670		20,968		19,598
Total Capitalization (Non-GAAP) - (d) + (g)					21,836		19,368		18,879
Average Total Capitalization (Non-GAAP)* - (h)					20,602		19,124		20,206
Return on Capital Employed (ROCE)
Calculated Using GAAP Net Income (Loss) - [(a) + (b)] / (h)      (Non-GAAP)					13.4 %		-4.8 %		-21.6 %
Return on Equity (ROE)
Calculated Using GAAP Net Income (Loss) - (b) / (e) (GAAP)					17.1 %		-8.1 %		-29.5 %
* Average for the current and immediately preceding year

ROCE & ROE
(Continued)

In millions of USD, except ratio data (Unaudited)
			2014		2013		2012		2011
Interest Expense, Net (GAAP)			201		235		214
Tax Benefit Imputed (based on 35%)			(70)		(82)		(75)
After-Tax Net Interest Expense (Non-GAAP) - (a)			131		153		139
Net Income (GAAP) - (b)			2,915		2,197		570
Total Stockholders' Equity - (d)			17,713		15,418		13,285		12,641
Average Total Stockholders' Equity* - (e)			16,566		14,352		12,963
Current and Long-Term Debt (GAAP) - (f)			5,906		5,909		6,312		5,009
Less:  Cash			(2,087)		(1,318)		(876)		(616)
Net Debt (Non-GAAP) - (g)			3,819		4,591		5,436		4,393
Total Capitalization (GAAP) - (d) + (f)			23,619		21,327		19,597		17,650
Total Capitalization (Non-GAAP) - (d) + (g)			21,532		20,009		18,721		17,034
Average Total Capitalization (Non-GAAP)* - (h)			20,771		19,365		17,878
Return on Capital Employed (ROCE)
Calculated Using GAAP Net Income - [(a) + (b)] / (h) (Non-      GAAP)			14.7 %		12.1 %		4.0 %
Return on Equity (ROE)
Calculated Using GAAP Net Income - (b) / (e) (GAAP)			17.6 %		15.3 %		4.4 %
* Average for the current and immediately preceding year

Revenues, Costs and Margins Per Barrel of Oil Equivalent

In millions of USD, except Boe and per Boe amounts (Unaudited)
EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who review certain components and/or groups of components of revenues, costs and/or margin per barrel of oil equivalent (Boe). Certain of these components are adjusted for non-recurring and certain other items, as further discussed below.   EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.
	2Q 2022		1Q 2022		4Q 2021		3Q 2021		2Q 2021
Volume - Million Barrels of Oil Equivalent - (a)	83.8		79.5		79.4		77.7		75.3
Total Operating Revenues and Other (b)	7,407		3,983		6,044		4,765		4,139
Total Operating Expenses (c)	4,504		3,437		3,516		3,294		2,968
Operating Income (d)	2,903		546		2,528		1,471		1,171
Wellhead Revenues
Crude Oil and Condensate	4,699		3,889		3,246		2,929		2,699
Natural Gas Liquids	777		681		583		548		367
Natural Gas	1,000		716		847		568		404
Total Wellhead Revenues - (e)	6,476		5,286		4,676		4,045		3,470
Operating Costs
Lease and Well	324		318		325		270		270
Transportation Costs	244		228		228		219		214
Gathering and Processing Costs	152		144		147		145		128
General and Administrative	128		124		139		142		120
Taxes Other Than Income	472		390		316		277		239
Interest Expense, Net	48		48		38		48		45
Total Operating Cost (excluding DD&A and Total Exploration Costs) (f)	1,368		1,252		1,193		1,101		1,016
Depreciation, Depletion and Amortization (DD&A)	911		847		910		927		914
Total Operating Cost (excluding Total Exploration Costs) - (g)	2,279		2,099		2,103		2,028		1,930
Exploration Costs	35		45		42		44		35
Dry Hole Costs	20		3		43		4		13
Impairments	91		55		206		82		44
Total Exploration Costs (GAAP)	146		103		291		130		92
Less:  Certain Impairments (1)	(36)		—		—		(13)		(1)
Total Exploration Costs (Non-GAAP)	110		103		291		117		91
Total Operating Cost (including Total Exploration Costs (GAAP)) - (h)	2,425		2,202		2,394		2,158		2,022
Total Operating Cost (including Total Exploration Costs (Non-GAAP)) - (i)	2,389		2,202		2,394		2,145		2,021
Total Wellhead Revenues less Total Operating Cost      (including Total Exploration Costs (GAAP))	4,051		3,084		2,282		1,887		1,448
Total Wellhead Revenues less Total Operating Cost      (including Total Exploration Costs (Non-GAAP))	4,087		3,084		2,282		1,900		1,449
Per Barrel of Oil Equivalent (Boe) Calculations (GAAP)
Composite Average Operating Revenues and Other per      Boe - (b) / (a)	88.39		50.10		76.12		61.33		54.97
Composite Average Operating Expenses per Boe - (c) / (a)	53.75		43.23		44.28		42.40		39.42
Composite Average Operating Income per Boe  - (d) / (a)	34.64		6.87		31.84		18.93		15.55
Composite Average Wellhead Revenue per Boe - (e) / (a)	77.29		66.50		58.88		52.07		46.07
Total Operating Cost per Boe (excluding DD&A and Total      Exploration Costs) - (f) / (a)	16.32		15.75		15.02		14.19		13.48
Composite Average Margin per Boe (excluding DD&A and      Total Exploration Costs) - [(e) / (a) - (f) / (a)]	60.97		50.75		43.86		37.88		32.59
Total Operating Cost per Boe (excluding Total Exploration      Costs) - (g) / (a)	27.19		26.40		26.48		26.12		25.61
Composite Average Margin per Boe (excluding Total      Exploration Costs) - [(e) / (a) - (g) / (a)]	50.10		40.10		32.40		25.95		20.46
Total Operating Cost per Boe (including Total Exploration      Costs) - (h) / (a)	28.94		27.70		30.15		27.79		26.85
Composite Average Margin per Boe (including Total      Exploration Costs) - [(e) / (a) - (h) / (a)]	48.35		38.80		28.73		24.28		19.22
Per Barrel of Oil Equivalent (Boe) Calculations (Non-GAAP)
Total Operating Cost per Boe (including Total Exploration      Costs) - (i) / (a)	28.50		27.70		30.14		27.62		26.82
Composite Average Margin per Boe (including Total      Exploration Costs) - [(e) / (a) - (i) / (a)]	48.79		38.80		28.74		24.45		19.25
(1) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total exploration costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated).

Revenues, Costs and Margins Per Barrel of Oil Equivalent
(Continued)

In millions of USD, except Boe and per Boe amounts (Unaudited)
	2021		2020		2019		2018		2017
Volume - Million Barrels of Oil Equivalent - (a)	302.5		275.9		298.6		262.5		222.3
Total Operating Revenues and Other (b)	18,642		11,032		17,380		17,275		11,208
Total Operating Expenses (c)	12,540		11,576		13,681		12,806		10,282
Operating Income (Loss) (d)	6,102		(544)		3,699		4,469		926
Wellhead Revenues
Crude Oil and Condensate	11,125		5,786		9,613		9,517		6,256
Natural Gas Liquids	1,812		668		785		1,128		730
Natural Gas	2,444		837		1,184		1,302		922
Total Wellhead Revenues - (e)	15,381		7,291		11,582		11,947		7,908
Operating Costs
Lease and Well	1,135		1,063		1,367		1,283		1,045
Transportation Costs	863		735		758		747		740
Gathering and Processing Costs	559		459		479		437		149
General and Administrative (GAAP)	511		484		489		427		434
Less:  Legal Settlement - Early Leasehold Termination	—		—		—		—		(10)
Less:  Joint Venture Transaction Costs	—		—		—		—		(3)
Less:  Joint Interest Billings Deemed Uncollectible	—		—		—		—		(5)
General and Administrative (Non-GAAP) (1)	511		484		489		427		416
Taxes Other Than Income	1,047		478		800		772		545
Interest Expense, Net	178		205		185		245		274
Total Operating Cost (GAAP) (excluding DD&A and Total Exploration Costs)      - (f)	4,293		3,424		4,078		3,911		3,187
Total Operating Cost (Non-GAAP) (excluding DD&A and Total Exploration      Costs) - (g)	4,293		3,424		4,078		3,911		3,169
Depreciation, Depletion and Amortization (DD&A)	3,651		3,400		3,750		3,435		3,409
Total Operating Cost (GAAP) (excluding Total Exploration Costs) - (h)	7,944		6,824		7,828		7,346		6,596
Total Operating Cost (Non-GAAP) (excluding Total Exploration Costs) - (i)	7,944		6,824		7,828		7,346		6,578
Exploration Costs	154		146		140		149		145
Dry Hole Costs	71		13		28		5		5
Impairments	376		2,100		518		347		479
Total Exploration Costs (GAAP)	601	601	2,259		686		501		629
Less:  Certain Impairments (2)	(15)		(1,868)		(275)		(153)		(261)
Total Exploration Costs (Non-GAAP)	586		391		411		348		368
Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) -       (j)	8,545		9,083		8,514		7,847		7,225
Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non-      GAAP)) - (k)	8,530		7,215		8,239		7,694		6,946
Total Wellhead Revenues less Total Operating Cost (GAAP) (including Total        Exploration Costs (GAAP))	6,836		(1,792)		3,068		4,100		683
Total Wellhead Revenues less Total Operating Cost (Non-GAAP) (including       Total Exploration Costs (Non-GAAP))	6,851		76		3,343		4,253		962

Revenues, Costs and Margins Per Barrel of Oil Equivalent
(Continued)

In millions of USD, except Boe and per Boe amounts (Unaudited)
	2021		2020		2019		2018		2017
Per Barrel of Oil Equivalent (Boe) Calculations (GAAP)
Composite Average Operating Revenues and Other per Boe - (b) / (a)	61.63		39.99		58.20		65.81		50.42
Composite Average Operating Expenses per Boe - (c) / (a)	41.46		41.96		45.81		48.79		46.25
Composite Average Operating Income (Loss) per Boe - (d) / (a)	20.17		(1.97)		12.39		17.02		4.17
Composite Average Wellhead Revenue per Boe - (e) / (a)	50.84		26.42		38.79		45.51		35.58
Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) -      (f) / (a)	14.19		12.39		13.66		14.90		14.34
Composite Average Margin per Boe (excluding DD&A and Total      Exploration Costs) - [(e) / (a) - (f) / (a)]	36.65		14.03		25.13		30.61		21.24
Total Operating Cost per Boe (excluding Total Exploration Costs) - (h) / (a)	26.26		24.71		26.22		27.99		29.67
Composite Average Margin per Boe (excluding Total Exploration Costs) -       [(e) / (a) - (h) / (a)]	24.58		1.71		12.57		17.52		5.91
Total Operating Cost per Boe (including Total Exploration Costs) - (j) / (a)	28.25		32.92		28.51		29.89		32.50
Composite Average Margin per Boe (including Total Exploration Costs) -       [(e) / (a) - (j) / (a)]	22.59		(6.50)		10.28		15.62		3.08
Per Barrel of Oil Equivalent (Boe) Calculations (Non-GAAP)
Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) -         (g) / (a)	14.19		12.39		13.66		14.90		14.25
Composite Average Margin per Boe (excluding DD&A and Total      Exploration Costs) - [(e) / (a) - (g) / (a)]	36.65		14.03		25.13		30.61		21.33
Total Operating Cost per Boe (excluding Total Exploration Costs) - (i) / (a)	26.26		24.71		26.22		27.99		29.59
Composite Average Margin per Boe (excluding Total Exploration Costs) -       [(e) / (a) - (i) / (a)]	24.58		1.71		12.57		17.52		5.99
Total Operating Cost per Boe (including Total Exploration Costs) - (k) / (a)	28.20		26.13		27.60		29.32		31.24
Composite Average Margin per Boe (including Total Exploration Costs) -       [(e) / (a) - (k) / (a)]	22.64		0.29		11.19		16.19		4.34
(1)  EOG believes excluding the above-referenced items from general and administrative expense is appropriate and provides useful information to investors, as EOG views such items as non-recurring.
(2) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total exploration costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated).

Revenues, Costs and Margins Per Barrel of Oil Equivalent
(Continued)

In millions of USD, except Boe and per Boe amounts (Unaudited)
		2016		2015		2014
Volume - Million Barrels of Oil Equivalent - (a)		205.0		208.9		217.1
Total Operating Revenues and Other (b)		7,651		8,757		18,035
Total Operating Expenses (c)		8,876		15,443		12,793
Operating Income (Loss) (d)		(1,225)		(6,686)		5,242
Wellhead Revenues
Crude Oil and Condensate		4,317		4,935		9,742
Natural Gas Liquids		437		408		934
Natural Gas		742		1,061		1,916
Total Wellhead Revenues - (e)		5,496		6,404		12,592
Operating Costs
Lease and Well		927		1,182		1,416
Transportation Costs		764		849		972
Gathering and Processing Costs		123		146		146
General and Administrative (GAAP)		395		367		402
Less:  Voluntary Retirement Expense		(42)		—		—
Less: Acquisition Costs		(5)		—		—
Less:  Legal Settlement - Early Leasehold Termination		—		(19)		—
General and Administrative (Non-GAAP) (1)		348		348		402
Taxes Other Than Income		350		422		758
Interest Expense, Net		282		237		201
Total Operating Cost (GAAP) (excluding DD&A and Total Exploration Costs) - (f)		2,841		3,203		3,895
Total Operating Cost (Non-GAAP) (excluding DD&A and Total Exploration Costs) - (g)		2,794		3,184		3,895
Depreciation, Depletion and Amortization (DD&A)		3,553		3,314		3,997
Total Operating Cost (GAAP) (excluding Total Exploration Costs) - (h)		6,394		6,517		7,892
Total Operating Cost (Non-GAAP) (excluding Total Exploration Costs) - (i)		6,347		6,498		7,892
Exploration Costs		125		149		184
Dry Hole Costs		11		15		48
Impairments		620		6,614		744
Total Exploration Costs (GAAP)		756		6,778		976
Less:  Certain Impairments (2)		(321)		(6,308)		(824)
Total Exploration Costs (Non-GAAP)		435		470		152
Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) - (j)		7,150		13,295		8,868
Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non-GAAP)) - (k)		6,782		6,968		8,044
Total Wellhead Revenues less Total Operating Cost (GAAP) (including Total  Exploration      Costs (GAAP))		(1,654)		(6,891)		3,724
Total Wellhead Revenues less Total Operating Cost (Non-GAAP) (including Total      Exploration Costs (Non-GAAP))		(1,286)		(564)		4,548

Revenues, Costs and Margins Per Barrel of Oil Equivalent
(Continued)

In millions of USD, except Boe and per Boe amounts (Unaudited)
		2016		2015		2014
Per Barrel of Oil Equivalent (Boe) Calculations (GAAP)
Composite Average Operating Revenues and Other per Boe - (b) / (a)		37.32		41.92		83.07
Composite Average Operating Expenses per Boe - (c) / (a)		43.30		73.93		58.92
Composite Average Operating Income (Loss) per Boe - (d) / (a)		(5.98)		(32.01)		24.15
Composite Average Wellhead Revenue per Boe - (e) / (a)		26.82		30.66		58.01
Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (f) / (a)		13.86		15.33		17.95
Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) /      (a) - (f) / (a)]		12.96		15.33		40.06
Total Operating Cost per Boe (excluding Total Exploration Costs) - (h) / (a)		31.19		31.20		36.38
Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (h) /      (a)]		(4.37)		(0.54)		21.63
Total Operating Cost per Boe (including Total Exploration Costs) - (j) / (a)		34.88		63.64		40.85
Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (j) /      (a)]		(8.06)		(32.98)		17.16
Per Barrel of Oil Equivalent (Boe) Calculations (Non-GAAP)
Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (g) / (a)		13.64		15.25		17.95
Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) /      (a) - (g) / (a)]		13.18		15.41		40.06
Total Operating Cost per Boe (excluding Total Exploration Costs) - (i) / (a)		30.98		31.11		36.38
Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (i) /      (a)]		(4.16)		(0.45)		21.63
Total Operating Cost per Boe (including Total Exploration Costs) - (k) / (a)		33.10		33.36		37.08
Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (k) /      (a)]		(6.28)		(2.70)		20.93

(1) EOG believes excluding the above-referenced items from general and administrative expense is appropriate and provides useful information to investors, as EOG views such items as non-recurring.

(2) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total exploration costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated).

 

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SOURCE EOG Resources, Inc.

FAQ

What were EOG Resources' total revenues for Q2 2022?

EOG Resources reported total revenues of $7.4 billion for Q2 2022.

When will EOG's special dividend be paid?

The special dividend of $1.50 per share will be paid on September 29, 2022.

What was EOG Resources' net income in Q2 2022?

EOG Resources' net income for Q2 2022 was $2.2 billion.

How much free cash flow did EOG generate in Q2 2022?

EOG generated $1.3 billion in free cash flow during Q2 2022.

What was the debt-to-total capitalization ratio for EOG Resources?

EOG Resources' debt-to-total capitalization ratio was 18.6% as of Q2 2022.