EOG Resources Reports Excellent First Quarter 2021 Results; Declares $1.00 per Share Special Dividend

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HOUSTON, May 6, 2021 /PRNewswire/ -- EOG Resources, Inc. (EOG) today reported first quarter 2021 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



1Q 2021


4Q 2020


1Q 2020



Total Revenue

3,694


2,965


4,718



Net Income

677


337


10



Net Income Per Share

1.16


0.58


0.02


GAAP

Net Cash Provided by Operating Activities

1,870


1,121


2,585


Total Expenditures

1,067


1,107


1,826



Current and Long-Term Debt

5,133


5,816


5,222



Cash and Cash Equivalents

3,388


3,329


2,907



Debt-to-Total Capitalization

19.8%


22.3%


19.6%




Adjusted Net Income

946


411


318



Adjusted Net Income Per Share

1.62


0.71


0.55



Discretionary Cash Flow

2,010


1,494


1,666


Non- GAAP

Cash Capital Expenditures before Acquisitions

945


828


1,685



Free Cash Flow

1,065


666


(19)



Net Debt

1,745


2,487


2,315



Net Debt-to-Total Capitalization

7.8%


10.9%


9.7%


First Quarter 2021 Highlights


  • Declared special dividend of $1.00 per share and regular quarterly dividend of $0.4125 per share, an indicated annual total cash return to shareholders of $1.5 billion

  • Earned an adjusted $1.62 per share, second-highest quarterly EPS in EOG history

  • Generated $1.1 billion of free cash flow, a quarterly record

  • Capital expenditures 6% below guidance midpoint driven by sustainable efficiency improvements

  • Oil production above high-end of guidance range

  • Made significant progress toward 5% well cost reduction goal in 2021

  • Reached agreement to divest China assets

Volumes and Capital Expenditures

Wellhead Volumes

1Q 2021


1Q 2021
Guidance
Midpoint


4Q 2020


1Q 2020

Crude Oil and Condensate (MBod)

431.0


425.1


444.8


483.3

Natural Gas Liquids (MBbld)

124.3


130.0


141.4


161.3

Natural Gas (MMcfd)

1,342


1,360


1,292


1,378

Total Crude Oil Equivalent (MBoed)

778.9


781.8


801.5


874.1





Cash Capital Expenditures before Acquisitions ($MM)

945


1,000


828


1,685

From William R. "Bill" Thomas, Chairman and Chief Executive Officer
"Our outstanding first quarter results and special dividend announcement reflect the power of EOG's returns-focused strategy. True to the EOG culture, our employees have embraced the higher hurdle rate with the shift to double-premium, which drove record returns in the first quarter. EOG continues to deliver sustainable improvements in operating performance, once again exceeding expectations.

"Our robust operating performance translates into financial results that allow us to deliver on our cash flow priorities. Earlier this year we raised the regular dividend and reduced debt outstanding. Our long-standing financial discipline now positions EOG to return additional cash to shareholders through a special dividend, bringing total expected return of cash to shareholders in 2021 to $1.5 billion.

"EOG is off to a great start in 2021 and I am confident that we will continue to get better going forward."

First Quarter 2021 Financial Performance

Adjusted Earnings per Share 1Q 2021 vs 4Q 2020

Prices and Hedges
Higher prices for crude oil, natural gas and natural gas liquids all contributed to higher earnings. Average crude oil prices increased to $58.02 per barrel in the 1Q from $41.81 per barrel in the 4Q, contributing about 60% of the $1.40 earnings per share increase attributable to higher prices. EOG also realized higher prices for a portion of natural gas sold on a spot basis during periods of strong demand related to winter storms and for natural gas sold at prices tied to LNG export markets. Price gains were partially offset by a decrease in hedge settlement value, to $30 million cash paid in 1Q from $72 million cash received in 4Q.

Volume
Overcoming downtime from Winter Storm Uri, which reduced 1Q production by approximately 3%, total company crude oil production of 431,000 Bopd was above the high end of the guidance range and just 3% lower than 4Q. NGL production was 12% lower, partially offset by a 4% increase in natural gas production, driven by the market-based decision to reduce ethane extraction. Total company equivalent volumes decreased 3%.

Per-Unit Costs
Total per-unit costs in 1Q were slightly above the mid-point of the guidance range, due to higher prices for fuel and power during the winter storm. Compared with 4Q, higher taxes other than income related to increased product prices accounted for about half the increase in per-unit costs. Higher fuel and power, DD&A and production-related costs also contributed to the increase.

Change in Cash 1Q 2021 vs 4Q 2020

Free Cash Flow
EOG generated discretionary cash flow (net cash provided by operating activities before exploration expense and changes in working capital) of $2.0 billion in 1Q. The company incurred $945 million of cash capital expenditures before acquisitions, resulting in $1.1 billion of free cash flow.

Capital Expenditures
Cash capital expenditures before acquisitions were below the midpoint of the guidance range due to lower well costs from sustainable efficiency improvements. Faster drilling times, more efficient completion operations and lower-cost sand and water sourcing contributed to lower overall well costs. EOG is well on track to meet or exceed its 5% well cost reduction goal for 2021.

Debt
On February 1, 2021, EOG repaid, with cash on hand, the $750 million aggregate principal amount of its 4.100% Senior Notes due 2021 that matured on that date.

First Quarter 2021 Operating Performance

Lease and Well
Per-unit LOE costs declined 7% compared with the prior‐year period due to lower water handling costs, workover costs and overall efficiency improvements. Per-unit LOE also was $0.10 below the 1Q 2021 guidance midpoint. Compared with the 4Q 2020, per-unit LOE costs increased slightly due to higher fuel and power prices during the winter storm and seasonal factors.

Transportation, Gathering and Processing
Per-unit transportation costs increased in 1Q as EOG expanded its transportation and storage capacity to provide greater flexibility and support higher price realizations. Higher fuel and power prices during the winter storm also contributed to increased transportation and gathering and processing costs.

General and Administrative
G&A costs on a per-unit basis were in-line with the 4Q 2020 and slightly below the guidance midpoint.

Depreciation, Depletion and Amortization
Per-unit DD&A costs in the 1Q were in-line with the target, which was higher compared with the 4Q due to negative price- related reserve revisions.

Special Dividend and China Divestiture

Declared $1.00 per Share Special Dividend
The Board of Directors declared a regular dividend of $0.4125 per share on EOG's Common Stock. The indicated annual rate is $1.65. The Board also declared a special dividend of $1.00 per share on EOG's Common Stock. Both dividends are payable July 30, 2021 to stockholders of record as of July 16, 2021.

China Divestiture
EOG reached an agreement to divest all of its assets in China for proceeds of approximately $140 million. Closing, subject to customary conditions, is expected in the second quarter of 2021. Current net production from the divested assets is approximately 25 MMcfd of natural gas.

First Quarter 2021 Results vs Guidance











































Crude Oil and Condensate (MBod)

1Q 2021


1Q 2021
Guidance
Midpoint


Variance


4Q 2020


3Q 2020


2Q 2020


1Q 2020

United States

428.7


423.0


5.7


442.4


376.6


330.9


482.7

Trinidad

2.2


2.0


0.2


2.3


1.0


0.1


0.5

Other International

0.1


0.1


0.0


0.1


0.0


0.1


0.1

Total

431.0


425.1


5.9


444.8


377.6


331.1


483.3

NGLs (MBbld)







Total

124.3


130.0


(5.7)


141.4


140.1


101.2


161.3

Natural Gas (MMcfd)







United States

1,100


1,125


(25)


1,075


1,008


939


1,139

Trinidad

217


215


2


192


151


174


201

Other International

25


20


5


25


31


34


38

Total

1,342


1,360


(18)


1,292


1,190


1,147


1,378








Total Crude Oil Equivalent Volumes (MBoed)

778.9


781.8


(2.9)


801.5


716.0


623.4


874.1

Total MMBoe

70.1


70.4


0.3


73.7


65.9


56.7


79.5








Capital Expenditures ($MM)

945


1,000


(55)


828


499


478


1,685








Benchmark Price







Oil (WTI) ($/Bbl)

57.80






42.67


40.94


27.85


46.08

Natural Gas (HH) ($/Mcf)

2.69






2.65


1.94


1.73


1.98








Crude Oil and Condensate ($/Bbl) - above (below) WTI







United States

0.27


0.20


0.07


(0.81)


(0.75)


(7.45)


0.89

Trinidad

(8.03)


(10.50)


2.47


(9.76)


(15.53)


(27.25)


(11.15)

Other International

(19.19)


(18.00)


(1.19)


(6.77)


(15.65)


20.93


11.43








NGLs - Realizations (% of WTI)

48.5%


49.0%


(0.5%)


41.1%


35.0%


36.6%


23.7%








Nat Gas ($/Mcf) - above (below) HH







United States

2.83


3.00


(0.17)


(0.36)


(0.45)


(0.62)


(0.48)

Natural Gas Realizations ($/Mcf)







Trinidad

3.38


3.35


0.03


3.57


2.35


2.13


2.17

Other International

5.66


5.70


(0.04)


5.47


4.73


4.36


4.32








Unit Costs ($/Boe)







Lease and Well

3.85


3.95


(0.10)


3.54


3.45


4.32


4.14

Transportation Costs

2.88


2.80


0.08


2.64


2.74


2.67


2.62

General and Administrative

1.57


1.65


(0.08)


1.54


1.89


2.32


1.44

Gathering and Processing

1.98


1.80


0.18


1.62


1.74


1.71


1.62

Cash Operating Costs

10.28


10.20


0.08


9.34


9.82


11.02


9.82

Depreciation, Depletion and Amortization

12.84


12.85


(0.01)


11.81


12.49


12.46


12.57








Expenses ($MM)







Exploration and Dry Hole

44


40


4


40


51


27


40

Impairment (GAAP)

44






143


79


305


1,573

Impairment (excluding certain impairments (non-GAAP))

43


70


(27)


57


52


66


57

Capitalized Interest

8


8


0


7


7


8


9

Net Interest

47


48


(1)


53


53


54


45








Taxes Other Than Income (% of Wellhead Revenue)

6.7%


7.0%


(0.3%)


5.1%


7.2%


9.4%


6.5%

Income Taxes







Effective Rate

23.2%


23.5%


(0.3%)


21.1%


19.2%


20.6%


68.4%

Deferred Ratio

(18%)


0%


(18%)


60%


330%


107%


743%

Second Quarter and Full-Year 2021 Guidance1





(Unaudited)








See "Endnotes" below for related discussion and definitions.

2Q 2021
Guidance Range


FY 2021
Guidance Range


2020
Actual


2019
Actual

Crude Oil and Condensate Volumes (MBod)












United States

436.0

-

446.0


433.0

-

444.0


408.1


455.5

Trinidad

1.5

-

2.3


1.0

-

1.8


1.0


0.6

Other International

0.0

-

0.2


0.0

-

0.2


0.1


0.1

Total

437.5

-

448.5


434.0

-

446.0


409.2


456.2

Natural Gas Liquids Volumes (MBbld)












Total

125.0

-

140.0


125.0

-

145.0


136.0


134.1

Natural Gas Volumes (MMcfd)












United States

1,110

-

1,210


1,110

-

1,210


1,040


1,069

Trinidad

195

-

225


180

-

220


180


260

Other International

10

-

22


5

-

15


32


37

Total

1,315

-

1,457


1,295

-

1,445


1,252


1,366

Crude Oil Equivalent Volumes (MBoed)












United States

746.0

-

787.7


743.0

-

790.7


717.5


767.8

Trinidad

34.0

-

39.8


31.0

-

38.5


30.9


44.0

Other International

1.7

-

3.9


0.8

-

2.7


5.4


6.2

Total

781.7

-

831.4


774.8

-

831.9


753.8


818.0













Benchmark Price












Oil (WTI) ($/Bbl)









39.40


57.04

Natural Gas (HH) ($/Mcf)









2.08


2.62













Crude Oil and Condensate Differentials - above (below) WTI2 ($/Bbl)




United States

(0.25)

-

0.75


(0.55)

-

1.45


(0.75)


0.70

Trinidad

(12.50)

-

(10.50)


(12.40)

-

(10.40)


(9.20)


(9.88)

Other International

(10.50)

-

(6.50)


(16.20)

-

(13.20)


3.68


0.36

Natural Gas Liquids - Realizations as % of WTI












Total

35%

-

45%


36%

-

48%


34.0%


28.1%

Natural Gas Differentials - above (below) NYMEX Henry Hub3 ($/Mcf)




United States

(0.40)

-

0.00


(0.25)

-

1.25


(0.47)


(0.40)

Natural Gas Realizations ($/Mcf)












Trinidad

3.10

-

3.60


3.10

-

3.60


2.57


2.72

Other International

5.40

-

5.90


5.20

-

6.20


4.66


4.44













Capital Expenditures4 ($MM)

1,000

-

1,200


3,700

-

4,100


...

3,490


6,234













Operating Unit Costs ($/Boe)












Lease and Well

3.45

-

4.15


3.50

-

4.20


3.85


4.58

Transport Costs

2.60

-

3.00


2.65

-

3.05


2.66


2.54

General and Administrative

1.50

-

1.60


1.50

-

1.60


1.75


1.64

Gathering and Processing

1.75

-

1.95


1.75

-

1.95


1.66


1.60

Cash Operating Costs

9.30

-

10.70


9.40

-

10.80


9.92


10.36

Depreciation, Depletion and Amortization

12.00

-

12.60


11.70

-

12.70


12.32


12.56













Expenses ($MM)












Exploration and Dry Hole

40

-

50


140

-

180


159


168

Impairment (GAAP)









2,100


518

Impairment (excluding certain impairments (non-GAAP))

45

-

95


255

-

295


232


243

Capitalized Interest

5

-

10


25

-

30


31


38

Net Interest

45

-

50


180

-

185


205


185













Taxes Other Than Income (% of Wellhead Revenue)

6.0%

-

8.0%


6.5%

-

7.5%


6.6%


6.9%

Income Taxes












Effective Rate

20%

-

25%


21%

-

26%


18.2%


22.9%

Deferred Ratio

0%

-

15%


0%

-

15%


54.8%


107.4%

First Quarter 2021 Results Webcast
Friday, May 7, 2021, 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, Trinidad, and China. To learn more visit www.eogresources.com.

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

Media and Investor Contact
Kimberly Ehmer 713‐571‐4676

Endnotes

1)

The forecast items for the second quarter and full year 2021 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.



2)

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.



3)

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.



4)

The forecast includes expenditures for Exploration and Development Drilling, Facilities, Leasehold Acquisitions, Capitalized Interest, Exploration Costs, Dry Hole Costs and Other Property, Plant and Equipment. The forecast excludes Property Acquisitions, Asset Retirement Costs and any Non-Cash Transactions.

Glossary


Acq

Acquisitions

ATROR

After-tax rate of return

Bbl

Barrel

Bn

Billion

Boe

Barrels of oil equivalent

Bopd

Barrels of oil per day

Capex

Capital expenditures

CO2e

Carbon dioxide equivalent

DCF

Discretionary cash flow

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," "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 goals or ambitions 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 or discretionary cash flow, 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 impairments and 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, 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 a...nd 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, natural gas liquids, 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, and competition for, 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 any changes or other actions which may result from the recent U.S. elections and change in U.S. administration and including tax laws and regulations; climate change and other environmental, health and safety laws and regulations relating to air emissions, 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;

  • 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 and economically;

  • competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties, employees and other personnel, facilities, equipment, materials and services;

  • the availability and cost of employees and other personnel, facilities, equipment, materials (such as water 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 use of competing energy sources and the development of alternative energy sources;

  • 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, 2020 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, 2020, 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 and calculation schedules for non‐GAAP financial measures can be found on the EOG website at www.eogresources.com.

Income Statements







In millions of USD, except per share data (Unaudited)






1Q 2021


4Q 2020


1Q 2020

Operating Revenues and Other




Crude Oil and Condensate

2,251



1,711



2,065


Natural Gas Liquids

314



229



161


Natural Gas

625



302



210


Gains (Losses) on Mark-to-Market Commodity Derivative
Contracts

(367)



70



1,206


Gathering, Processing and Marketing

848



643



1,039


Gains (Losses) on Asset Dispositions, Net

(6)



(6)



16


Other, Net

29



16



21


Total

3,694



2,965



4,718








Operating Expenses






Lease and Well

270



261



330


Transportation Costs

202



195



208


Gathering and Processing Costs

139



119



128


Exploration Costs

33



41



40


Dry Hole Costs

11






Impairments

44



143



1,573


Marketing Costs

838



621



1,110


Depreciation, Depletion and Amortization

900



870



1,000


General and Administrative

110



113



114


Taxes Other Than Income

215



114



157


Total

2,762



2,477



4,660








Operating Income

932



488



58


Other Income (Expense), Net

(4)



(7)



18


Income Before Interest Expense and Income Taxes

928



481



76


Interest Expense, Net

47



53



45


Income Before Income Taxes

881



428



31


Income Tax Provision

204



91



21


Net Income

677



337



10








Dividends Declared per Common Share

0.4125



0.3750



0.3750


Net Income Per Share






Basic

1.17



0.58



0.02


Diluted

1.16



0.58



0.02


Average Number of Common Shares






Basic

580



580



578


Diluted

583



581



580


Wellhead Volumes and Prices

(Unaudited)









1Q 2021


1Q 2020


% Change


4Q 2020









Crude Oil and Condensate Volumes (MBbld) (1)






United States

428.7



482.7



-11%



442.4


Trinidad

2.2



0.5



340%



2.3


Other International (2)

0.1



0.1



0%



0.1


Total

431.0



483.3



-11%



444.8










Average Crude Oil and Condensate Prices ($/Bbl) (3)








United States

58.07



46.97



24%



41.86


Trinidad

49.77



34.93



43%



32.91


Other International (2)

38.61



57.51



-33%



35.9


Composite

58.02



46.96



24%



41.81










Natural Gas Liquids Volumes (MBbld) (1)








United States

124.3



161.3



-23%



141.4


Total

124.3



161.3



-23%



141.4










Average Natural Gas Liquids Prices ($/Bbl) (3)








United States

28.03



10.94



156%



17.54


Composite

28.03



10.94



156%



17.54










Natural Gas Volumes (MMcfd) (1)








United States

1,100



1,139



-3%



1,075


Trinidad

217



201



8%



192


Other International (2)

25



38



-34%



25


Total

1,342



1,378



-3%



1,292










Average Natural Gas Prices ($/Mcf) (3)








United States

5.52



1.50



268%



2.29


Trinidad

3.38



2.17



56%



3.57


Other International (2)

5.66



4.32



31%



5.47


Composite

5.17



1.67



209%



2.54










Crude Oil Equivalent Volumes (MBoed) (4)








United States

736.4



833.8



-12%



763.0


Trinidad

38.5



34.0



13%



34.2


Other International (2)

4.0



6.3



-37%



4.3


Total

778.9



874.1



11%



801.5










Total MMBoe (4)

70.1



79.5



-12%



73.7











(1)

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

(2)

Other International includes EOG's China and Canada operations.

(3)

Dollars per barrel or per thousand cubic feet, as applicable. Excludes the impact of financial commodity derivative instruments (see Note 12 to the Condensed Consolidated Financial Statements in EOG's Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2021).

(4)

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

Balance Sheets

In millions of USD, except share data (Unaudited)


March 31,


December 31,


2021


2020

Current Assets




Cash and Cash Equivalents

3,388



3,329


Accounts Receivable, Net

1,828



1,522


Inventories

562



629


Assets from Price Risk Management Activities



65


Income Taxes Receivable



23


Other

413



294


Total

6,191



5,862



Property, Plant and Equipment




Oil and Gas Properties (Successful Efforts Method)

65,645



64,793


Other Property, Plant and Equipment

4,590



4,479


Total Property, Plant and Equipment

70,235



69,272


Less: Accumulated Depreciation, Depletion and Amortization

(41,569)



(40,673)


Total Property, Plant and Equipment, Net

28,666



28,599


Deferred Income Taxes

4



2


Other Assets

1,310



1,342


Total Assets

36,171



35,805



Current Liabilities




Accounts Payable

1,945



1,681


Accrued Taxes Payable

449



206


Dividends Payable

239



217


Liabilities from Price Risk Management Activities

188




Current Portion of Long-Term Debt

39



781


Current Portion of Operating Lease Liabilities

269



295


Other

183



280


Total

3,312



3,460






Long-Term Debt

5,094



5,035


Other Liabilities

2,178



2,149


Deferred Income Taxes

4,825



4,859


Commitments and Contingencies








Stockholders' Equity




Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 583,843,561
Shares Issued at March 31, 2021 and 583,694,850 Shares Issued at December
31, 2020

206



206


Additional Paid in Capital

5,979



5,945


Accumulated Other Comprehensive Loss

(14)



(12)


Retained Earnings

14,606



14,170


Common Stock Held in Treasury, 232,249 Shares at March 31, 2021 and 124,265
Shares at December 31, 2020

(15)



(7)


Total Stockholders' Equity

20,762



20,302


Total Liabilities and Stockholders' Equity

36,171



35,805


Cash Flows Statements

In millions of USD (Unaudited)





1Q 2021


4Q 2020


1Q 2020


Cash Flows from Operating Activities




Reconciliation of Net Income to Net Cash Provided by Operating
Activities:




Net Income

677


337


10


Items Not Requiring (Providing) Cash




Depreciation, Depletion and Amortization

900


870


1,000


Impairments

44


143


1,573


Stock-Based Compensation Expenses

35


33


40


Deferred Income Taxes

(36)


55


45


(Gains) Losses on Asset Dispositions, Net

6


6


(16)


Other, Net

7


10


(9)


Dry Hole Costs

11




Mark-to-Market Commodity Derivative Contracts




Total (Gains) Losses

367


(70)


(1,206)


Net Cash Received from (Payments for) Settlements of
Commodity Derivative Contracts

(30)


72


84


Other, Net

1


2



Changes in Components of Working Capital and Other Assets and
Liabilities




Accounts Receivable

(308)


(464)


722


Inventories

64


31


103


Accounts Payable

172


427


434


Accrued Taxes Payable

243


(61)


(55)


Other Assets

(103)


(90)


58


Other Liabilities

(89)


21


(66)


Changes in Components of Working Capital Associated with Investing
Activities

(91)


(201)


(132)


Net Cash Provided by Operating Activities

1,870


1,121


2,585


Investing Cash Flows




Additions to Oil and Gas Properties

(875)


(785)


(1,566)


Additions to Other Property, Plant and Equipment

(42)


(56)


(123)


Proceeds from Sales of Assets

5


3


26


Changes in Components of Working Capital Associated with Investing
Activities

91


201


132


Net Cash Used in Investing Activities

(821)


(637)


(1,531)


Financing Cash Flows




Long-Term Debt Repayments

(750)




Dividends Paid

(219)


(220)


(167)


Treasury Stock Purchased

(10)


(1)


(5)


Proceeds from Stock Options Exercised and Employee Stock Purchase
Plan


8



Repayment of Finance Lease Liabilities

(9)


(6)


(3)


Net Cash Used in Financing Activities

(988)


(219)


(175)


Effect of Exchange Rate Changes on Cash

(2)


(2)



Increase in Cash and Cash Equivalents

59


263


879


Cash and Cash Equivalents at Beginning of Period

3,329


3,066


2,028


Cash and Cash Equivalents at End of Period

3,388


3,329


2,907


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), Discretionary Cash Flow, 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 is included in the tables below and can also be found in the "Reconciliations & Guidance" section of the "Investors" page of the EOG website at www.eogresources.com.


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. 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), Total 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 per share data (Unaudited)









1Q 2021


Before

Tax


Income Tax

Impact


After

Tax


Diluted

Earnings

per Share









Reported Net Income (GAAP)

881



(204)



677



1.16


Adjustments:








Losses on Mark-to-Market Commodity Derivative Contracts

367



(81)



286



0.49


Net Cash Payments for Settlements of Commodity Derivative Contracts

(30)



7



(23)



(0.04)


Add: Losses on Asset Dispositions, Net

6



(1)



5



0.01


Add: Certain Impairments

1





1




Adjustments to Net Income

344



(75)



269



0.46










Adjusted Net Income (Non-GAAP)

1,225



(279)



946



1.62










Average Number of Common Shares (GAAP)








Basic







580


Diluted







583



















4Q 2020


Before

Tax


Income Tax

Impact


After

Tax


Diluted

Earnings

per Share









Reported Net Income (GAAP)

428



(91)



337



0.58


Adjustments:








Gains on Mark-to-Market Commodity Derivative Contracts

(70)



15



(55)



(0.10)


Net Cash Received from Settlements of Commodity Derivative Contracts

72



(16)



56



0.10


Add: Losses on Asset Dispositions, Net

6



(1)



5



0.01


Add: Certain Impairments

86



(18)



68



0.12


Adjustments to Net Income

94



(20)



74



0.13










Adjusted Net Income (Non-GAAP)

522



(111)



411



0.71










Average Number of Common Shares (GAAP)








Basic







580


Diluted







581


















Adjusted Net Income (Loss)







In millions of USD, except per share data (Unaudited)









1Q 2020


Before

Tax


Income Tax

Impact


After

Tax


Diluted

Earnings

per Share









Reported Net Income (GAAP)

31



(21)



10



0.02


Adjustments:








Gains on Mark-to-Market Commodity Derivative Contracts

(1,206)



265



(941)



(1.62)


Net Cash Received from Settlements of Commodity Derivative Contracts

84



(18)



66



0.11


Less: Gains on Asset Dispositions, Net

(16)



3



(13)



(0.02)


Add: Certain Impairments

1,516



(320)



1,196



2.06


Adjustments to Net Income

378



(70)



308



0.53










Adjusted Net Income (Non-GAAP)

409



(91)



318



0.55










Average Number of Common Shares (GAAP)








Basic







578


Diluted







580










Adjusted Net Income per Share

In millions of USD, except share and per Boe data (Unaudited)

4Q 2020 Adjusted Net Income per Share (Non-GAAP)



0.71






Realized Price




1Q 2021 Composite Average Wellhead Revenue per Boe

45.49




Less: 4Q 2020 Composite Average Wellhead Revenue per Boe

(30.39)




Subtotal

15.10




Multiplied by: 1Q 2021 Crude Oil Equivalent Volumes (MMBoe)

70.1




Total Change in Revenue

1,059




Less: Income Tax Benefit (Cost) Imputed (based on 23%)

(243)




Change in Net Income

815




Change in Diluted Earnings per Share



1.40






Net Cash Received (Paid) from Settlements of Commodity Derivative Contracts




1Q 2021 Net Cash Received (Paid) from Settlement of Commodity Derivative
Contracts

(30)




Less: Income Tax Benefit (Cost)

7




After Tax - (a)

(23)




4Q 2020 Net Cash Received (Paid) from Settlement of Commodity Derivative
Contracts

72




Less: Income Tax Benefit (Cost)

(16)




After Tax - (b)

56




Change in Net Income - (a) - (b)

(79)




Change in Diluted Earnings per Share



(0.14)






Wellhead Volumes




1Q 2021 Crude Oil Equivalent Volumes (MMBoe)

70.1




Less: 4Q 2020 Crude Oil Equivalent Volumes (MMBoe)

(73.7)




Subtotal

(3.6)




Times: 1Q 2021 Composite Average Margin per Boe (Non-GAAP)
(Including Total Exploration Costs) (refer to "Costs per Barrel of Oil Equivalent"
schedule)

17.38




Change in Revenue

(63)




Less: Income Tax Benefit (Cost) Imputed (based on 23%)

14




Change in Net Income

(48)




Change in Diluted Earnings per Share



(0.08)






Operating Cost per Boe




4Q 2020 Total Operating Cost per Boe (Non-GAAP) (including Total Exploration
Costs) (refer to "Costs per Barrel of Oil Equivalent" schedule)

24.72




Less: 1Q 2021 Total Operating Cost per Boe (Non-GAAP) (including Total
Exploration Costs) (refer to "Costs per Barrel of Oil Equivalent" schedule)

(28.11)




Subtotal

(3.39)




Times: 1Q 2021 Crude Oil Equivalent Volumes (MMBoe)

70.1




Change in Before-Tax Net Income

(238)




Less: Income Tax Benefit (Cost) Imputed (based on 23%)

55




Change in Net Income

(183)




Change in Diluted Earnings per Share



(0.31)






Other Items



0.04






1Q 2021 Adjusted Net Income per Share (Non-GAAP)



1.62






1Q 2021 Average Number of Common Shares (Non-GAAP) - Diluted

583




Discretionary Cash Flow and Free Cash Flow

In millions of USD (Unaudited)







1Q 2021


4Q 2020


1Q 2020







Net Cash Provided by Operating Activities (GAAP)

1,870



1,121



2,585








Adjustments:






Exploration Costs (excluding Stock-Based Compensation Expenses)

28



36



32


Other Non-Current Income Taxes - Net Receivable





113


Changes in Components of Working Capital and Other Assets and
Liabilities






Accounts Receivable

308



464



(722)


Inventories

(64)



(31)



(103)


Accounts Payable

(172)



(427)



(434)


Accrued Taxes Payable

(243)



61



55


Other Assets

103



90



(58)


Other Liabilities

89



(21)



66


Changes in Components of Working Capital Associated with Investing
Activities

91



201



132


Discretionary Cash Flow (Non-GAAP)

2,010



1,494



1,666








Discretionary Cash Flow (Non-GAAP) - Percentage Increase

35%












Discretionary Cash Flow (Non-GAAP)

2,010



1,494



1,666


Less:






Total Cash Capital Expenditures Before Acquisitions (Non-GAAP) (a)

(945)



(828)



(1,685)


Free Cash Flow (Non-GAAP)

1,065



666



(19)








(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)
for the three-month periods ended December 31, 2020 and March 31, 2021 and 2020:







Total Expenditures (GAAP)

1,067



1,107



1,826


Less:






Asset Retirement Costs

(17)



(48)



(20)


Non-Cash Expenditures of Other Property, Plant and Equipment






Non-Cash Acquisition Costs of Unproved Properties

(22)



(69)



(24)


Non-Cash Finance Leases

(74)



(101)



(49)


Acquisition Costs of Proved Properties

(9)



(61)



(48)


Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)

945



828



1,685


Discretionary Cash Flow and Free Cash Flow

In millions of USD (Unaudited)

















FY 2020


FY 2019


FY 2018


FY 2017









Net Cash Provided by Operating Activities (GAAP)

5,008



8,163



7,769



4,265










Adjustments:








Exploration Costs (excluding Stock-Based Compensation Expenses)

126



113



125



122


Other Non-Current Income Taxes - Net (Payable) Receivable

113



239



149



(513)


Changes in Components of Working Capital and Other Assets and
Liabilities








Accounts Receivable

(467)



92



368



392


Inventories

(123)



(90)



395



175


Accounts Payable

795



(169)



(439)



(324)


Accrued Taxes Payable

49



(40)



92



64


Other Assets

(325)



(358)



125



659


Other Liabilities

(8)



57



(11)



90


Changes in Components of Working Capital Associated with
Investing and Financing Activities

(75)



115



(301)



(90)


Discretionary Cash Flow (Non-GAAP)

5,093



8,122



8,272



4,840










Discretionary Cash Flow (Non-GAAP) - Percentage Increase (Decrease)

-37%



-2%



71%



76%










Discretionary Cash Flow (Non-GAAP)

5,093



8,122



8,272



4,840


Less:








Total Cash Capital Expenditures Before Acquisitions (Non-GAAP) (a)